RA-15-0003, License Amendment Request - Adoption of TSTF-510, Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection, Using the Consolidated Lune Item Improvement Process

License Amendment Request - Adoption of TSTF-510, Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection, Using the Consolidated Lune Item Improvement Process

ML15119A224
Person / Time
Site:	Oconee, Mcguire, Catawba, McGuire   (DPR-038, DPR-047, DPR-055, NPF-009, NPF-017, NPF-035, NPF-052)
Issue date:	04/16/2015
From:	Repko R Duke Energy Carolinas
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
RA-15-0003
Download: ML15119A224 (78)

Text

!eDE

• T Rfko DUKE 526 SoLO Owrd Sret ENRGY.

hdtA I AE Code ECO7HI/P.O. Boxft I

Quwtf NC2#20?.U)38 704-3828426 704..,60W6 fax Serial: RA-15-0003 10 CFR 50.90 April 16, 2015 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 CATAWBA NUCLEAR STATION, UNIT NOS. 1 AND 2 DOCKET NOS. 50-413 AND 50-414 / RENEWED LICENSE NOS. NPF-35 AND NPF-52 MCGUIRE NUCLEAR STATION, UNIT NOS. 1 AND 2 DOCKET NOS. 50-369 AND 50-370 / RENEWED LICENSE NOS. NPF-9 AND NPF-17 OCONEE NUCLEAR STATION, UNIT NOS. 1, 2 AND 3 DOCKET NO. 50-269, 50-270 AND 50-287 / RENEWED LICENSE NOS. DPR-38, DPR-47 AND DPR-55

SUBJECT:

UCENSE AMENDMENT REQUEST.

ADOPTION OF TSTF-510, REVISION V0 $TEAM GENERATOR PROGRAM INSPECTION FREQUENCIES AND TUBE SAMPLE SELECTION, USING THE CONSOUDATED LUNE ITEM IMPROVEMENT PROCESS Pursuant to 10 CFR 50.90, Duke Energy Carolinas, LLC ( ODuke Energy"), hereby requests a license amendment to the Technical Specifications (TS) for Catawba Nuclear Station, Unit Nos. 1 and 2 (CNS), McGuire Nuclear Station, Unit Nos. 1 and 2 (MNS), and Oconee Nuclear Station, Unit Nos. 1, 2, and 3 (ONS).

The proposed amendment would modify TS requirements regarding steam generator tube inspections and reporting as described in TSTF-510, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection." provides a description and assessment of the proposed changes, the requested confirmation.of applicability, and plant-specific verifications. Enclosure 2 provides the existing TS pages marked up to show the proposed changes. Enclosure 3 provides revised (clean) TS pages. Enclosure 4 provides existing TS Bases pages marked up to show the proposed changes. Changes to the existing TS Bases will be Implemented under the Technical Specification Bases Control Program. They are provided in Enclosure 4 for Information only.

The proposed changes have been evaluated in accordance with 10 CFR 50.91 (a)(1) using criteria in 10 CFR 50.92(c), and it has been determined that the proposed changes Involve no significant hazards consideration. The bases for these determinations are Included in.

This submittal contains no regulatory commitments.

3..\\

U.S. Nuclear Regulatory Commission RA.1 5-0003 Page 2 Approval of the proposed amendment is requested by April 16, 2016. Approval within the requested timeframe will support potential application of the proposed changes for steam generator inspection activities during the scheduled Fall 2016 CNS Unit 2 refueling outage.

Once approved, the amendment will be implemented within 120 days.

In accordance with 10 CFR 50.91, Duke Energy is notifying the States of North Carolina and South Carolina of this license amendment request by transmitting a copy of this letter and enclosures to the designated State Officials.

Should you have any questions concerning this letter, or require additional information, please contact Art Zaremba, Manager - Nuclear Fleet Ucensing, at 980-373-2062.

I declare under penalty of perjury that the foregoing is true and correct. Executed on April 16, 2015.

Sincerely, Regis T. Repko Sr. Vice President - Governance, Projects, and Engineering MKL

Enclosures:

1. Description and Assessment

2. Proposed Technical Specification Changes (Mark-up)

3. Revised Technical Specification Pages

4. Proposed Technical Specification Bases Changes (Mark-Up)

U.S. Nuclear Regulatory Commission RA-15-0003 Page 3 cc:

USNRC Region II G. A. Hutto, Ill, USNRC Resident Inspector - CNS J. Zeiler, USNRC Resident Inspector - MNS E. L. Crowe, USNRC Resident Inspector - ONS G. E. Miller, NRR Project Manager - CNS & MNS J. R. Hall, NRR Project Manager - ONS J. A. Whited, NRR Project Manager W. L. Cox, Ill, Chief, North Carolina Department of Health and Human Services, RP Section (NC)

S. E. Jenkins, Manager, Radioactive and Infectious Waste Management (SC)

U.S. Nuclear Regulatory Commission RA-15-0003 Page 4 bcc:

Chris Nolan Art Zaremba Mike Leisure Lara Nichols David Cummings Dan Mayes Parker Downing File: (Corporate)

Electronic Licensing Library (ELL)

Kelvin Henderson Cecil Fletcher Tolani Owusu Lee Keller Chuck Cauthen North Carolina Municipal Power Agency No. 1 (NCMPA)

Piedmont Municipal Power Agency (PMPA)

North Carolina Electric Membership Corporation (NCEMC)

CNS Master File 801.01 - CN04DM Toni Pasour (For CNS Licensing/Nuclear Records)

Steven Capps Jeff Robertson P.T. Vu MNS Master File 801.01 - MG02DM Kay Crane (For MNS Licensing/Nuclear Records)

Scott Batson Chris Wasik David Halle ONS Master File 801.01 - ON03DM Judy Smith (For ONS Licensing/Nuclear Records) to RA-15-0003 Enclosure I RA-15-0003 Description and Assessment to RA-1 5-0003 Page 1 of 4

1.0 DESCRIPTION

The proposed change revises:

o Catawba Nuclear Station, Unit Nos. 1 and 2 (CNS) Technical Specifications (TS) 3.4.18, "Steam Generator (SG) Tube Integrity," TS 5.5.9, "Steam Generator (SG) Program," and TS 5.6.8, "Steam Generator (SG) Tube Inspection Report";

1. McGuire Nuclear Station, Unit Nos. 1 and 2 (MNS) TS 3.4.18, 'Steam Generator (SG)

Tube Integrity," TS 5.5.9, "Steam Generator (SG) Program," and TS 5.6.8, "Steam Generator Tube Inspection Report"; and o Oconee Nuclear Station, Unit Nos. 1, 2, and 3 (ONS) TS 3.4.16, "Steam Generator (SG)

Tube Integrity," TS 5.5.10, "Steam Generator (SG) Program," and TS 5.6.8, "Steam Generator Tube Inspection Report."

The proposed changes are needed to address implementation issues associated with the inspection periods, and address other administrative changes and clarifications.

The proposed amendment is consistent with Technical Specification Task Force (TSTF)

Traveler 510 ("TSTF-51 0"), Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection."

2.0 ASSESSMENT

2.1 ApDlicabllitv of Published Safety Evaluation Duke Energy has reviewed TSTF-510, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection," (ADAMS Accession No. ML110610350),

and the model safety evaluation (ADAMS Accession No. MLI 12101513), as identified in the Federal Register Notice of Availability dated October 27, 2011 (76 FR 66763). As described in the subsequent paragraphs, Duke Energy has concluded that the justifications presented In TSTF-510 and the model safety evaluation prepared by the NRC staff are applicable to Catawba Nuclear Station, Unit Nos. 1 and 2, McGuire Nuclear Station, Unit Nos. 1 and 2, and Oconee Nuclear Station, Unit Nos. 1, 2, and 3, and justify this amendment for the incorporation of the changes to the CNS, MNS, and ONS TS.

2.2 Optional Chanoes and Variations Duke Energy is proposing the following variations from the TS changes described In the TSTF-510, Revision 2, or the applicable parts of the NRC staff's model safety evaluation:

The CNS, MNS, and ONS TS utilize different numbering than the Standard Technical Specifications (STS) on which TSTF-510 was based. The specific numbering differences are:

TSTF-510 Rev. 2 Corresponding Corresponding Westinghouse Owner's Group (WOG) STS CNS TS MNS TS 3.4.20, "Steam Generator (SG) Tube Integrity" 3.4.18 3.4.18 5.6.7, "Steam Generator Tube Inspection Report" 5.6.8 5.6.8 to RA-15-0003 Page 2 of 4 TSTF-510 Rev. 2 Corresponding Babcock & Wilcox Owner's Group (BWOG) STS ONS TS 3.4.17, -Steam Generator (SG) Tube Integrity.

3.4.16 5.5.9, "Steam Generator (SG) Program" 5.5.10 5.6.7, "Steam Generator Tube Inspection Report" 5.6.8

" The proposed change corrects an administrative inconsistency in TSTF-510, Paragraph d.2 of the Steam Generator Tube Inspection Program. In Section 2.0, "Proposed Change," TSTF-510 states that references to "tube repair criteria" in Paragraph d is revised to "tube plugging for repair] criteria." However, In the following sentence in Paragraph d.2, this change was Inadvertently omitted:

If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tub repair crii, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. (Emphasis added)

Duke Energy does not have approved tube repair criteria. Therefore, the sentence is revised to state "tube plugging" criteria. In a June 17, 2013, letter to the Technical Specification Task Force (ADAMS Accession No. ML13120A541), responding to a March 28, 2012 TSTF letter (ADAMS Accession No. ML12088A082), the NRC staff stated that correction of this administrative error will not result in the submittal being removed from the Consolidated Line Item Improvement Process (CLIPP).

" The Westinghouse Owner's Group (WOG) STS markups in TSTF-510 apply to CNS.

Note that CNS Unit No. I has a different SG design than CNS Unit No. 2. Therefore, the current CNS TS 5.5.9 includes requirements specific to Unit No. I and requirements specific to Unit No. 2. The proposed TS markups for CNS incorporate the intent of the TSTF-510 changes, while retaining the Unit-specific formatting of the existing CNS TS.

" The existing CNS TS 5.5.9.d.2 includes a definition of the acronym "EFPM" as being "Effective Full Power Months". This acronym is used later in existing CNS TS 5.5.9.d.4.

CNS TS 5.5.9.d.2 is proposed to be replaced with a new section from TSTF-510 that uses the term "effective full power months" but does not define the acronym. The proposed TS markup for CNS adds the acronym.

These differences are administrative and do not affect the applicability of TSTF-510 to the CNS, MNS, and ONS TS.

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Determination Duke Energy requests adoption of an approved change to the standard technical specifications (STS) into the plant specific technical specifications (TS) regarding Steam Generator (SG) tube integrity, the SG administrative requirements, and the SG tube inspection reporting to RA-1 5-0003 Page 3 of 4 requirements. These changes address inspection periods and other administrative changes and clarifications. The specific TS affected are:

Catawba Nuclear Station, Unit Nos. 1 and 2 TS 3.4.18, "Steam Generator (SG) Tube Integrity," TS 5.5.9, "Steam Generator (SG) Program," and TS 5.6.8, "Steam Generator (SG) Tube Inspection Report";

" McGuire Nuclear Station, Unit Nos. 1 and 2 (MNS) TS 3.4.18, "Steam Generator (SG)

Tube Integrity," TS 5.5.9, "Steam Generator (SG) Program," and TS 5.6.8, "Steam Generator Tube Inspection Report"; and

" Oconee Nuclear Station, Unit Nos. 1, 2, and 3 (ONS) TS 3.4.16, "Steam Generator (SG)

Tube Integrity," TS 5.5.10, "Steam Generator (SG) Program," and TS 5.6.8, "Steam Generator Tube Inspection Report."

As required by 10 CFR 50.91 (a), an analysis of the issue of no significant hazards consideration is presented below:

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

Response: No.

The proposed change revises the Steam Generator (SG) Program to modify the frequency of verification of SG tube integrity and SG tube sample selection. A steam generator tube rupture (SGTR) event is one of the design basis accidents that are analyzed as part of a plant's licensing basis. The proposed SG tube inspection frequency and sample selection criteria will continue to ensure that the SG tubes are inspected such that the probability of a SGTR is not increased. The consequences of a SGTR are bounded by the conservative assumptions in the design basis accident analysis. The proposed change will not cause the consequences of a SGTR to exceed those assumptions. Therefore, it is concluded that this change does not Involve a significant increase in the probability or consequences of an accident previously evaluated.

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

Response: No.

The proposed changes to the Steam Generator Program will not introduce any adverse changes to the plant design basis or postulated accidents resulting from potential tube degradation. The proposed change does not affect the design of the SGs or their method of operation. In addition, the proposed change does not impact any other plant system or component.

Therefore, it is concluded that this change does not create the possibility of a new or different kind of accident from any accident previously evaluated.

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

Response: No.

The SG tubes in pressurized water reactors are an integral part of the reactor coolant pressure boundary and, as such, are relied upon to maintain the primary system's pressure and Inventory. As part of the reactor coolant pressure boundary, the SG tubes are unique in that they are also relied upon as a heat transfer surface between the primary and secondary systems such that residual heat can be removed from the primary system. In addition, the SG tubes also isolate the radioactive fission products in to RA-1 5-0003 Page 4 of 4 the primary coolant from the secondary system. In summary, the safety function of a SG is maintained by ensuring the integrity of its tubes.

Steam generator tube integrity is a function of the design, environment, and the physical condition of the tube. The proposed change does not affect tube design or operating environment. The proposed change will continue to require monitoring of the physical condition of the SG tubes such that there will not be a reduction in the margin of safety compared to the current requirements.

Therefore, it is concluded that the proposed change does not involve a significant reduction in a margin of safety.

Based on the above, Duke Energy concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and accordingly, a finding of "no significant hazards consideration" is justified.

4.0 ENVIRONMENTAL EVALUATION The proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

to RA-1 5-0003 RA-164)00 Proposed Technical Specification Changes (Marlt.u)

SG Tube Integrity 3.4.18 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.18 Steam Generator (SG) Tube Integrity.

LCO 3.4.18 SG tube integrity shall be maintained-.

All SG tubes satisfying the tu hall be plugged In accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2,3, and 4.

ACTIONS Separate

.ondition entry-----NOTE--

Separate Condition entry is allowed for each SG tube.-

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes ng the tube P

~riteria and not

~ýplgged in accordance with the Steam Generator Program.

A.1 Verify tube integrity of the affected tube(s) is maintained until the next Inspection.

7 days Prior to entering MODE 4 following the next refueling outage or SG tube inspection A.2 Plug the affected tube(s) in accordance with the Steam Generator Program.

4 (continued)

Catawba Units I and 2 3.4.18-1 Amendment Nos. etf-

SO Tube Integrity -

3.4.18, ACTIONS (continued):

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and 8.1 Be In MODE 3.

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

B2 Be in MODE 5.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.18.1 Verify SG tube integrity in accordance with the In accordance Steam Generator Program.

with the Steam Generator Program SR 3.4.182 Verify that each Inspected SG tube that S fi threu pa " criteria is plugged In accordance with the Steam Generator

• Program.

Prior to entering MODE 4 following a SG tube inspection

ý Catawba Units I and 2

..3.4.18-2 Amendment Nos. 2-.-124e

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.8 Inservice Testina Proaram This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include the following:

a.

Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies for Addenda terminology for performing inservice testing inservice testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less for performing inservice testing activities;

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d.

Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator (SG) Proaram A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is majntatbad;Aaddition, the Steam Generator Program shall include the followingpamftiem)

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the *as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the (continued)

Catawba Units I and 2 5.5-6 Amendment Nos. 260947

Programs and Manuals.

5.5.

5.5 Programs and Manuals-55.9 Steam Generator (SG) Prooram (continued) condition of the tubing during a SG inspection outage, as determined from the Inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are Inspected or plugged to confirm that the performance criteria are being met.

b.

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

Structural integrity performance criterion: All inservice SG tubes shall retain structural integrity over the full range of normal operating conditions (including st rtup, operation in the power range, hot standby, an

ooo, and all anticipated transients included in the design specificatlon),nd design basis accidents.

This Includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary to secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary to secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents In accordance with the.

design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse.

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

2.

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

Leakage is not to exceed 150 gallons per day through each SG for a total of 600 gallons per day through all SGs.

3.

The operational LEAKAGE performance criterion Is specified in LCO 3.4.13, "OCS Operational LEAKAGE.

c.

Provisions for SG tA e

faeda. Tubes found by inservice inspection to contain flaws With a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

(continued)

Catawba Units 1. and 2 5.5-7 Amendment Nos. 248M22-

Programs and Manuals 5-;5 5.5 Programs and Manuals 5.5.9 Steam Generator (SGI Proaram (0 The following SG tube alternate I shall be applied as an alternative to the 40*/ depth based criteria:

1.

For Unit 2 only, tubes with service-induced flaws located greater than 14.01 inches below the top of the tubesheet do not require plugging. Tubes with service-induced flaws located In the portion of the tube from the top of the tubesheet to 14.01 inches below the top of the tubesheet shall be plugged upon detection.

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. For Unit 1, the number and portions of the tubes inspected and method of inspection shall be performed with the objective of detecting flaws of any type (for example, volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tsh weld at the tube outlet, and that may satisfy the applicable tubeft p

,j,.ý criteria. The tube-to-tubesheet weld Is not part of the tube. For Unit 2, the number and portions of the tubes inspected and method of inspection shall be performed with the objective of detecting flaws of any type (for example, volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from 14.01 inches below the top of the tubesheet on the hot leg side to 14.01 inches below the top of the tubesheet on the cold leg side, and that may satisfy the applicable tube I Ov riteria. In addition to meeting requirements d.1, d.2, d.3, and d.4 l

I Inspection scope, inspection methods, and inspection Intervals shall be such as to ensure that SG tube Integrity is maintained until the Snext S in-speotio-n~i,-; I,,,--,-;";

.d-"-t..

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

(continued)

Catawba Units I and'2 5.5-7a Amendment Nos. 26MS8 -

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 SSteam Gmenertor 18Gl Proaram (continued)

1.

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

2.

ýFor Unit 2, inspect 100% of the tubes at sequentlal periofls0 144, 108, 72, and, thereafter, 60 Effective Full Prs ita erodh shal(EFPM). The first sequential period sh e

dered to begin S

5.after the firsts.

In addition, Inspectiofttus by the ing

-C ros tO.5 -Z.

.,o th tubesob the ruel nearef outage nearnest the midpoint of

• the period and the tng 50% by the refueling outage nearest vthe rnd of t ls)io No SG shall operate for more than 72

3. /For 'Unit 2, insec 100}% of the tubes at sequential 120, 90, and, thereafter, 60 EFPM. The firs t

Il period I( t* G"A-7 shall be considered to begin aft, ins'*service inspection of c(" ý

5. S.". 9. *.

)

Ithe SGs. In addition, Inspect Oof the tubes by the refueling Ioutage nearest the mjxid~ o the period and the remaining 50%/

[by the refueling.ta nearest the, end of the period. No SIGI '

shl v

or isoless wthout 4bein ort o ins e

fuelin outge

4.

For-Unit 1,lf crackr tions are found in any SG tube, then the next-Inspection for each)PG for the degradation mechanism that caused the crack indication shall not exceed 24 EFPM or one refueling outage (whicheverA-less). For Unit 2, if crack Indications are found in any SG tube from 14.01 Inches below the top of the tubesheet on the hot leg side to 14.01 Inches below the top of the tubesheet on the cold leg side, then the next inspection or eacý SG for the degradation mechanism that caused the crack indicatioh shall not exceed 24 EFPM or one refueln outage (wheination o f

a ed tube irmation,-such as from examination of a pulled tube, diagnostic non-dlestructive testing, or engineering evaluation Indicates that a crack-like indication is not associated with crack(s), then the indication need C

.+[eC.C...co allined

____________________(continued)

I Catawba Units I and 2 5.5-'S Amendment Nos. 26MS

( o L*",J*eS "-tt1LSPrograms and Manuals Porm5.5 5.5 Programs and Manuals 5.5.9 Steam Generator J,') Prooram (continued) not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

5.5.10 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a.

Identification of a sampling schedule for the critical variables and control points for these variables;

b.

Identification of the procedures used to measure the values of the critical variables;

c.

Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage;

d.

Procedures for the recording and management of data;

e.

Procedures defining corrective actions for all off control point chemistry conditions; and

f.

A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

5.5.11 Ventilation Filter Testing Proaram (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems In accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1980, with exceptions as noted in the UFSAR.

a.

Demonstrate for each of the ESF systems that an inpilace test of the high efficiency particulate air (HEPA) filters shows the following penetration and system bypass when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI N510-1980 at the flowrate specified below

• 10%.

(continued)

Catawba Units I and 2 5.5-9 Amendment Nos. 218/212

INSERT ONS 5.5.9.d.2

2.

For Unit 1, after the first refueling outage following SG installation, inspect each SG at least every 72 effective full power months (EFPM) or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled Inspection shall be the number of tubes in all SGe divided by the number of SG inspection outages scheduled in each Inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the Inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled tobe inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to Include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b)

During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; C)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, Inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent Inspection periods.

INSERT CNS 5.5.9.d.3 §,r:

-". ;,c.*,

3.

For Unit 2, after the first refueling outage following SG installation, inspect each SG at least every 48 effective full power months or at leastrevery'other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes-in all, SGs divided by the number of.jnSa ectiop toages scheduled in each inspection pipd as defi.ned in a, b,'and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique duuno the reminder offthe" Inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradatiqn at this location at

.the endof the inspetion period shall benotless thenthe ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination.that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be Inspected in the Inspection pedod.. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage In an inspectlonperlod and the subsequent inspection period begins at the conclusion of the included SG Inspection outage.

-a),

After the first refueling outage following

,ri'sii inspect 100%06 of the tubepsduring the next 120 effectl full S.

power months. This constitutes the first inspection period;

-,b)

.During the next 96 effective full power months, Inspect

-"." % of the tubes.: Thisconstitutes the second impection 4,.

tubes eiiy 72 effetlve full power months. This c

• C.

Sh---th

.dan:i s.rtse Ains peIon periods.

-~ C,~

fReporiUng Requemnents 5.6 5.8 fstegoa ReAurMM l (con dinud 5.6.8 owOA UM)L OA A repoW shett boe omttd wl*t I8 dIyS fterror Iitil entrf InI MODE 4 foloWtng completin of fte nspReon. The reprt shag kwcft M (*

a oInspeins peftrme an each SG.

I).

• ra*daton m hn isms found, C.

Non-dosruoe eaamlnatlo tehie utilized for eoti* degradaio mechnism.

4.

Location oetation (if linea). and ftMeae~d Sims (If available) of serviomm Iuced n om, tkmibe of tuesl d durin

• a" I

oua e

oR eei j

de dtwon meanch~.

f.

9.

The m. f0ts d Confm man"l, I

dn thasuita of tube pds annd m-lot, tesflg,

h.

For Unt 2. *th p ar b second y LFM(AGE rote oburjWd in each SG (if it Is not pr a to doanp lkge to an NOW*

SO, ft oenr prima to *econM L

AGE should bt cc WvWy asmumed b be from one SO) durg the cyce pOeeding th Ro oM W" fs @se sub*)c of the r"poCt I.

For Unit 2. tf calojted aocdet Mkake rate on ftm poron of tho "uOs beWow 14.01 incM from fte top of the tbheshet for e most imitng ascdent b the mowt,mitng SO.

f n adition, w

mi cahloft d acddent Wekage rate frnm ire most liitng accident is auh 3.27 tmes Me maximum prVnway to omondary LEM(AGE rate, the report shall deacrib htw it was Odeteried, mad l

For unit 2, ft esuwt of montrng for Mte axia dbpaemen (ul*pege). If uopg Is dssovrd. deb rpic*a*tio of the dwcvet and

¢xamtk Ivo4-44Lj.e..r tve r~Jj~AJ

,CPC.CA4 i

e-mcAC xk-a~v1--

C*Wwbs Ufft I MW 2

.6.t*

Anwxkwt NW.260-ln-r

SG Tube lntegrity, 3.418 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.18 Steam Generator (SG) Tube Integrity LCO 3.4.18 SG tube Integrity shall be maintained.

AND All SG tubes satisfying the t accordance with the Steam

,.iteria shall be plugged in Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS SearteCodtin..... salow o e NOTI Separate Condition entry is allowed for each SG tt CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes A.1 Verify tube integrity of the 7 days satisfying the tube affected tube(s) is criteria and not plugged maintained until the next in accordance with the refueling outage or SG Steam Generator tube inspection.

P_

pA.2 Plug the affected tube(s) In Prior to entering accordance with the Steam MODE 4 following the Generator Program.

next refueling outage or SG tube inspection B. Required Action and 8.1 Be in MODE 3.

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion rime of Condition A not AN met.

B.2 Be in MODE 5.

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

McGuire Units I and-2 3.4.18.1 Amendment Nos. 287-4,1-

SG Tube Integrity 3.4.18 SURVEILLANCE REQUIREMENTS..

SURVEILLANCE FREQUENCY SR 3.4.18.1 Verify SG tube integrity in accordance with the In accordance Steam Generator Program.

with the Steam Generator Program SR 3.4.18.2 Verify that each inspected SG tube that satisfies the Prior to entering tub~ejsela criteria is Mlugged in accordance with the MODE 4 following Q-SF~Generator Programn.

a SO tube inspection McGuire Units 1 and 2 3.4.18-2

,/

Amendment Nos. fff-ft

'Programs and Manuals 5.5 5.5 Programs and-Manuals (continued) 5.5.8 Inservice Testin ProMmram This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include the following:

a.

Testing frequencies applicable to the ASME Code for Operation and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies for Addenda terminology for performing inservice testing inservice testing activities activities we At least onceper 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less In the Inservice Testing Program for performing inservice testing activitles; C.

The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d.

Nothing in the ASME Boiler OM Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator ISG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube t

ntained. In addition, the Steam Generator Program shall include the following

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging (continued)

McGuire Units I and 2 5.5-6 Amendment No. 262=2

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SGQ Proaram (continued) of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

b.

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

1.

Structural integrity performance criterion: All In-service steam generator tubes shall retain structural integrity over the full rae of normal operatin conditions (including startup, operation in the power range, hot standby, and cool down all anticipated transients included in the design specification)'fnd design basis accdents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primay-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents In accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed In combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident Induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed In the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 0.27 gallons per minute total.

3.

The operational LEAKAGE performance criterion Is specified in LCO 3.4.13, "RCS Operational LEAE....-!

c.

Provisions for SQ tube ria. Tubes found by Inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

(continued)

McGuire Units I and 2 5.5-7 Amendment No. 2370249--

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Proam (continued)

d.

Provisions for SG tube Inspections. Periodic SG tube inspections shall be performed. The Fnumber and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable pariterda. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, Inspection methods, and inspection Intervals shall be such as to ensure that SG tube Integrity is maintained unti the next SG Inspection. An a.....m...

of dogradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessme me which Inspection me fts need to be employed and at what locations. A s4*L.,,

va.e.o'?*,S

1.

n 100% of the tubes In each SG durng the first refueling outage following SG

2. Tnpct I the tubes at sequential perds of 144,108,72, a "60 effective full power months. The first sequential considered to begin N.) S after the first Inservice inspection n addition, inspect 50%1 of the tubes by the refueling outage midpoint of the period and the remaining 50% by the refueling outa arest the end of the period. No S133 shall operate for more than 72 full power months or three refueling outages (whichever Is less) ben ia _.d.

97

3.

If crack indications are found in any SG tube, then the next inspection for each 0 for the degradation mechanism that caused the crack indication shall not ex effective full pwer months or one refuelin outage (whicheverjp-le

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

{

e.

Provisions for monitoring operational' primarny" to secodayLEAKAGE.rat et 4-c c-44avwl9 fec4ntn1 4

ued (continued)

McGuire Units I and 2 5.5-8 Amendment No. 29M219

INSERTMNS 5..9:d.2R

2.

After the first refueling outage following SG installation, Inspect each SG at least every 72 effective full power months or at least every third refueling outage (whlchqver results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled Inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled In each Inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the Inspection period shal be no lese than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SO inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b)

During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Stam Generat TUbelnsoe2tion Reoo A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an Inspection performed In accordance with the Specification 5.5.9, Steam Generator (SG) Program. The report shall include:

a.

.Tjhe ofI ons performed on each SG,

b.

enisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

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

e.

Number of tubes plugged during the Inspection outage for each j

degradation mechanism,

g.

The results of condition monitoring, including the results of tube pulls AiX r~. f 4ýee'464e 4

fI VJsolij ec I.

(continued)

McGuire Units I and 2.

5.6-5

Amendment Nos. 28-7-/-2lt

SO Tube integrityI 3.4.16 I 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 Steam Generator (SG) Tube Integrity LCO 3.4.16 SO Tube integrity shall be maintained.

All SO tubes satisfying the tube criteria shall be plugged in accordance with the Steam G on r Program.

I APPLICABILITY:

MODES 1, 2,3, and 4.

ACTIONS Separate Condition entry is allowed for each S(

5

• S.S.aSflbS.aSinbSaOaOS*.aaSaO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SO tubes A.1 Verify tube integrity of 7 days satisfying the tube the affected tube(s) is

,paw criteria and not maintained until the plugged in accordance next refueling outage with the Steam or SO tube inspection.

Generator Program.

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

tube inspection B.

Required Action and B.1 Be in MODE 3.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SO tube integrity not maintained.

OCONEE UNITS 1,2, & 3 3.4.16-1 Amendment Nos. 36,.5v-&-o6 I

SQ Tube Integrity I 3.4.16 I SURVEILLANCE REQUIREMENIS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify SG tube Integrity in accordance with In accordance with the the Steam Generator Program.

Steam Generator Program SR 3.4.16.2 Verify that each Inspected SG tube that satisfies the tuben criteria Is plugged in accoance witn mhe Steam Generator Program.

Prior to entering MODE 4 following an SO tube inspection OCONEE UNITS 1, 2, & 3 3.4.16-2 Amendment Nos. 355,8,"7, & -,"

I

Programs and Manuals 5.5:

5.5 Programs and Manuals

.5.5.9 Inservice Testing Proaram (continued)

ASME Boiler and Pressure Vessel Code and applicable Addenda terminology for inservice testing act....es Weekly Monthly Quarterly or every 3 months Semiannually or every 6 months Every 9 months Yearly or annually Biennially or every 2 years Required Frequencies for performing inservice testin actieities At least once per 7 days At least once per 31 days At least once per 92 days At least once per 184 days At least once per 276 days At least once per 366 days At least once per 731 days I

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies for performing inservice testing activities;

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d.

Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any TS.

5.5.10 Steam G02

() trarn I

A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintaie.In addition, the Steam Generator Program shall include the followjntwW

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SO tubes are inspected or plugged to confirm that the performance criteria are being met.

OCONEE UNITS 1, 2. & 3 5.0-13 Amendment Nos. 266, 367.,,&

I

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Steam GeneMrt (SQ) Proram (continued)

b. Performance Criteria for SG tube integrity. SO tube Integrity shall be maintained by meeting the performance criteria for tube ructura Integrity, accident Induced leakage, and operational LEAKAGE.

1. Structural Integrity performance criterion: AN In-service steam generator tubes shall retain structural Integrity over the full range of norml operating conditions (in'cding startup, operation In the power range, hot sta y, an cool wnif all anticipated transients included in the design speclficationfand design basis accidents. This Includes retaining a safety factor of 3.0 against burst under normal steady Mte full power operation primary-to-secondary pressure differential and a safely factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentlals. Aa from the above requirements, additional loading conditions associated wih the deeIn basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine If the aseoclated to&ds contribute significantly to burst or collapse. In the assessment of tube Integrity, those loads that do significantly affec burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primar loads and 1.0 on &xial secondary loads.

2. Accident Induced leakage performance criterion: The primary to secondary accident Induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed In the accident analysis in terms of total leakage rate for all SO* and leakage rate for an Individual SO. Leakage is not to exceed 150 gallons per day per SO.

3. The operational LEAKAGE performance criern Is ied In LCO 3.4.13, -RCS Operational LEAKAGE."

T

c. Provisions for SG tube oepir tda. Tubes 51ie inspection to 4-contain flaws with a depth equal to or exoeeding 40% of the nominal tube wall thickness shall be plugged.

d. Provisions for SO tube Inspections. Periodic tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube Inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the

.al?[icable tubejer criteria. The tube-to-tubesheet weld is not part of the OCONEE UNITS 1, 2, & 3 5.0-14 Amendment Nos.

,5-,W?--A7 1

Programs and Manuals 5.5 5.5 - Programs and Manuals 5.5.10 SIM Generator (Gl PErram (continued) 1 C147ftd tube. In addition to meeting the requirements

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

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

1. Inspect 100%.(*.ajJgs In each SG during the first refueling outage'

2. Inpec 1 t

tubes at I periods of 144, 1 thereafter, 60 effective full power months. The fikss ntia period I '

shall be considered to beginfflr the fir inspection of the SGs.

oIn addition, inspect 50% of the refueling outage nearest the s 5.to. J midpoint of the period and remaining 50% by the refueling outage nearesttheendof nod. NoSGshalloperateformorethan 72 effective f r months or three refueling outages (whichever is less) ng inspected.

3. If crack Indications are found In any SG tube, then the next inspection for eec SG for the degradation mechanism that caused the crack indication not exceed 24 effective full power months or one refueling outage (whichever i&lee9.

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

e. Provisions for monitoring operational primary to secondary LEAKAGE.E]

C ~

r eL p4eA 41,q((;t 44-r-OCONEE UNITS 1, 2, & 3 5.0-15 Amendment Nos. 355, 367,-&

I

INSERT ONS 5-5-10-d-2

2.

After the first refueling outage following SG installation, inspect each SG at least every 72 effective full power months or at least every third refueling outage (whichever results In more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes In all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location dMded by the total number of times the SO is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage In an inspection period and the subsequent inspection period begins at the conclusion of the Included SG inspection outage.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period;

-b)

• During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspectioui period; c)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7 Tendon Surveillance Recort Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken.

5.6.8 Steam Generator Tube lr on Re8orM A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed In accordance with Specification 5.5.10, Steam Generator (SG) Program. The report shall include:

a.

of ie on each SG,

b.

ound

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

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

e.

Number of tubes plugged during the inspection outage for each@

-F) degradation mechanism,

g.

The results of condition monitoring, including the results of tube pulls and F.

inTshu tesfing gind.--ntgor-l 7

CA t4vs c

c,- c OCONEE UNITS 1. 2, & 3 5.0-28 Amendment Nos. 886, M0, &

7 I

to RA-15-0003

'.~.

T°,_,,

RA-15-0003 Rv'sed Technical Specification Pages 5

• so TubSO-3:4 REACr COOLANT SYSTEM (R=)

3.4.18 S0i0m

• Ao(SG)Tube 0It LCO 3.4.18 SO tube inMty ed ael mbehiteb I.

i I

AN 0 S

• ft tube pftn cae e d" be PlugWd In aco*lcane w the $smm onaor Prgrm.

APPLICABILITY:

40OOE 1, 2.3 and 4.

ACONS S

aConditon ent is -

for each SG tube.

CoNomoN f*WIREDACTM*

4 COMPLE TM E A. Orvoor mm SG Ubm A.1 Veriiyftkubp*Geyf I

saufin the tub thefeclsdUb(s)f plugging orude and aintae un u

Wet not ad ln -nh...,in accornce* wtt Steam Glenraw Program A-2 Plug One effeted babes)

Prior to rn In'scordW.

with No MOOE41oIkfolg..

Steam Generator t

nts rofue*lng.

Program.

outage or SO tube bumonk (cem..,, d)

I CatAw Unite I Wnd 2 UA4.11

-mn~e Nw.

~,~S6qab IAtegMIy 3.4.18 A'&?ION (continuedl' cmomor~~

REQUIRED ACTION COMPLETION TIME S

o B. Required Acti and 8.1 fe In MODE 3.

6 hors asociated Competion Thm of Conditon A not met.

8.2 BInMODEs.

asiam SG tube intgutty no.

mabntined.

SURVEILLAWNCE RQIEET SURVEHAANCE FREQUENCY SR 3.4A18.1 Ve~ Qtb igt~acrmc ihteIn ocrdnen Stea GsnemraW Pmgram.

with doe Stowm sue ve,

..~..........

SR 3.4.12.2 VeftS ta each lspesd so t"e* ht Pr W t Ms d the #0 M* kofg

• MO Citeias plugged In MOOS 4 acordame wfth the Steam Genestor fotowing a Se Program.

tU Iepeon I

.v*

'.4

-C.

C40tefbaUnVAtwd

%818 AWO 2.

$3.4.1W.

Programs and Manuab 5.5 5.8 frorms mgd Manwis (contine) 5.5.6 Imlaft Tum Pmm This p*rwm prOYn cont* 1 isro mfine AS&*E Cod Cs, 1. 2.

end3 coenpn*mnslchdnq g apies pregra dhab kwI~edw

a.

Teeinq hquncIwA apploabi. to hw ASME Cods for Operatons and Maktenmene of NudbiVw er Plaii (ASME OM Cafd)

Wd appcab AddMndO W fonbm:

ASME 00 CoM s maanda *lipll PNir Fr*quanaw s for Addends tWmfrde for paefonnig NOWNIaMs u ftIs

., s f WOeAkl At %Wt once per I dos man"hl At W"tOM W 31 dsy Ckau* edor vsey3 monfts Atsse once pe 92 dap Seminnual1y or wi S monxds Atleat oW e pem W14 dayp Evey 0 monls Atlstonapepr*t7*Sm YwV or amumy At 6M ow per 3W dep lennlmy or evwy 2 ys At 6lmt oncepn days

b.

The provfswon of OR 3.0.2 are eepboM Io ft ob oN@ reqadmd Frquences and to other normaml an smlmd Fp o.o qpieified s 2 yn or kem for pwefoir kionrAie inuin aculiMet C.

The Proebm of SR 3.0.3 ans *00h to bm~e th edlhI1a;

d.

NoUMON In 1h AM* O Code *Whb be conou I*

o pwsade ft raqidem a oany TB.

A Seam Gumemr Propin ahaB be estblihed an Impem d to ensure sof 0 ith ogy is e in*bw. i s onm te stea GWator Pgram sha incudthe o lein*

IL Prviio for wm a

ntu a

mea.

Comndon mw*ng meunet mmns an evaoaUon of the 's found" cnd onof fe tibing wih mepecl d the ew O ne owmeulsa for sucr ltety ed accdent induced leakae. The "s found condti rfero to #ia COMwMe Unts I

.d 2

5.54

.Programs and Manuals..

" +

... 5.5,

5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued) condition of the tubing during a SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

b.

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

,1.

Structural integrity performance criterion: All inservice SG tubes shall retain structural integrity over the full range of normal operating. conditions (including startup, operation in the power ra.nge,'hot standby, and cooldown), all anticipated transients included in th.design specification, and desigh basis acc'idents.*

This includes, retaining, a safety factor of 30 against bursf under normal steady state full power operation prihmary to secondary

• pressure differential and a safety factor of 1 4 ag~inst burst applied to the design basis-accident primary to secondary' pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in. accordance~with the

. design and licensing. basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse.,

In the assessment of tube integrity, those loads that do significant"ly affect burst.or collapse shall be determined and

~. ",assessed.in combination with the loads due to pressure with a

,safety factor. of 1.2 on the combined primary loads and 1.0 on axialsecondary loads.

2.

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

Leakage is not to exceed 150 gallons per day through each SG for a total of 600 gallons per day through all SGs.

3.

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

c.

Provisions for SG tube plugging criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

(continued)

Catawba Units 1 and 2 5.5-7 Amendment Nos.

5.5 ftggMMn go4 Mawulft TMe tOlbWin SO WWh 4bW~ft phigin *Ofta hub be appiioa an

1.

For nik 2 orgy, bhes wil toe1 c WI dueed flw baied oft fthen4.01 Odn~hosbloM Vietp of theIbaslt

~do notmqub pkokq~n.

Tubeswith srqic4cskjwe ftnogob6w ~pou*Io' of toe %be**

frM e %pot ciUVwtsstd I* U.01, hitoeow Nle WoP of Me bAMehee bii"be uipon OstusiNI

d.

Provkisin for 96 thbe lnepotie.

PssUW aO

'Be i b

poll vi be petlonwd. For UMn

%--jeadsrmfw~e hspeotd and neftod of kwecWo 00ehe psv~blimW wil w0 *0eb ve at desiteft"n atw any Msv (for eism* vohnetic fson =kg owd from toe UW*4o4*sbiss vo~d atl 6wibe Inlet ft 6w 0thuli wsd at MUwtbsoK end 00-tm" so*f #* eppgiIbe Use phiggiti aftfte.

T110 fheouehe l oitp t Ei e for Unit2.

slid be reu~ poom wis off*~ o d

~ o e~4 exwnpb; voluebi lowiS oxbi*

v~p iscntu l ci acs) VOW m~be

~rsn a**n fw,*e Ien ff te Mt ow. 1W4.01 Incl-below wtolp of VietutaA w,eest

.viottw

~eoI~~

14.01 MOche beobw Vitop off -,

tusbeehe on"h cow tog li aiW OWhat mesynsduy"PM Mi

~u We b

4.4bsbnowV1b kis~n aco*e InScinmt ods wo ~ISO -

k6.ruW ghbe uvhe t bn thx&At SWo bb Ir*slv,* 110114 ld perfftwmd to dobwnsl fti *ap andlfo Io of two 10 v#ch Vie bAb may be suscepibe and. base on Oft asnoeeeml ib detuml Movtlh bisupectoe mdied ft"e to toev""ye adi at wIui loftlfsn A '~

Jr M-0 1,i Lbe I w1gd25.4 iusts 5.54

-Ali -- w-106 1 i me ft 4.

Programs Wd Manuas 5.5

&.5 ola~msad bumals 5.5.9 atow n L t (confte)

Z.

for Unkt 1. aftp the ft iWusy ouepe ftowing SO instulaton, in1ec eac 8G at isas evv 72 ate*

f powr mantis (EPPM) or it AN" ta " iLV Map ("ce m"Ots In mou *"AM kopewOns). In adiOn ft inm n m*mw of trim Inspete at eac schduled Ivpo she le the nmbrd w8Glmnedlvl Idhed bylhsnu~mbof8G InsaclonagW e ewduled In each kmpetn p*e as delned In a. b, c and d bebw. 0

• degadaion, assessment Irdllesa the potmul fora type of degradation boems o

t e cOMo not prloudy hed wth a l*tiqmue cap e of detecn #i t" of degW edMa alfft aml d4 may satisfy toaicble tha e

ps.

Is. the mhlmum number of locabons nspeced wilt vcdh a capabe inspseion lOchnle dwbf the rmsinder of go In*plod n Vei may be arorate The tracdton of Waft m bt Inspeed for Oile peeire tVpe of degraon at this location at tie end of Ow k*inepsodn period WuWbeno asr Om the rafo of fte numberofmmese O SIs sched ed Io be Inspected In te kupecin elod o*fer Ve "ultato n oratva fame olfdegnedeon ccIopam. tbe OCCUwkq tIGhtiOs loadion *0ed by tIe UMta numiber of Imes the 80 is0. o f

tobeinpth ed In fIe inepcl a per*io.

Each inspection perWo define below meyte ewauuded up to 3 etective W pmw monthhe 1to *cl a pseO oft Ig n aen Inspection pero anW fth sbeeqMM iNsecton period begins at the condualon of t Iincludod 80 Impacton ouboae.

a)

After the fist rexfusn outage fafolowlg SO k*Wadon, hospect 100% of the %Am during ft next 144 effscve full power months.7hsconesthhasa No fir ist pedion pwW-b)

Owing toe next 120 sfedM fud pm mnftis Inspect 100% of the UM". TM consotuies

• • t second inspeftin C)

Ouing e next 96 effctive fll power monihs. Inspec 100% of the tub"s. Thes onhftites, the fth Inspection perid;, and d)

During the remaining We of the Sf, taspect 100% of fth tubes every 72 effectIve power monthe. Thie oanAtituw the fourth nd susequnt Inpection peodai.

(oonank")

(conth~sd)

Catnoe Uns I and 2 U-0e AmnwnWem MOL

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

3.

For Unit 2, after the first refueling outage following SG installation, inspect each SG at least every 48 effective full power months or at least every other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 120 effective full power months. This constitutes the first inspection period; b)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; and c)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods

4.

For Unit 1, if crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 EFPM or one refueling outage (whichever results in more frequent inspections). For Unit 2, if crack indications are found in any SG tube from 14.01 inches below the top of the (continued)

Catawba Units 1 and 2 5.5-10 Amendment Nos.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued) tubesheet on the hot leg side to 14.01 inches below the top of the tubesheet on the cold leg side, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 EFPM or one refueling outage (whichever results in more frequent inspections). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

Catawba Units 1 and 2 (continued)

Amendment Nos.

5.5-11

Propems wid

° 6.6 5.5.10 TIis proram proVs c ohb f monlDft Geoedwy wSe dhsnksb to I~,it SG Ume degdation and Jow prsuN tbi od s

oM WMuM

-wi I. The pogrmn shd indud

e.

fdentIfcatbon of a umlngq*

• scheuls for tVe a'iltc iVWbWe.rd cWrWbul point for time vika*bs;

b.

ldenslation of tht poouk ed O

o msum tgo VWm of 0!

aM ci varI*es; C.

IdeMnIctlon of proces sampl llm l

W hts.

Ofch shO llVIndo monl19 tedi rue.of e cOfto ndn pmnpf *vi* n of codenW In

d.

ProcsduuM for the rcordlng ed mmmhgemeI" lo daIM;

o.

P~rmcedlm dafni% arocft acfto f*d off 0o11 int chembMfy corditon; and

f.

A procew e

tdent*m ifng 1 auoy vuemponmW for e ine alon of the date nd fth sequenc and ftim of emntrmanshIchs requtnd to Wliut oondm

• acnm.

5.5.11 VnllnRtrT mrm+VT' A progrmn sha be eWtblhe to mplement fte fo lgm MWequr tein" of Eno. eied Set FastuisW

ý40 (6SF) Uter vwentlaon syjoem in accordmm* wit Regla Ouydu 1.62, Rfevlon 2, ard ANSI NONO, wt psamlons Ns noted In "h UFSAA

a.

O fore ech of Ue E' sy&stms j= #

n pcs hof th h eoelency ptlculat air (HEPA)Uleis hOwn i ft oin pentraio amid y"snem byp whenmesd.in saco*rdn* wift ebgoddoy Gue 1.*.Z RPeism 2. anMd ASI N510,19W a the fnowrb spoled below *10%.

CeaweUnts 1 and 25.2 ndeNo

&S-.12

P5.5lm ir adnu IN

• 55 5.5 Prorm s an M 5.5.11 ismfm WI(O ESF Ventiution Sysm Anmuus Venatbion Cono Room Area VentiaUon Auw Mldg FWled 5 ut ComnWne Pure (non-ESF) (2 am)

Fuel Bld Veantlaon and Sysem owm A 1%

0.05%

41%

-1%

9000 dm SoM dm 30,000 Om 25.O0 odm 118.66 oht

b.

Demnsrav te for. smA of to OSF systems tot an i.nplace %ds of ft, carbon -

sheor

• n fokit*e* g penshtion ad sW"anm byuss when *estd In

omomn, Wileh elatory Gusde 1.S2. RevAsbn 2. and ANSI N0510-1N0 at fth *om spuMl below

• 10%.

ESF VtetdMlon Syslme pndS alms Fkwr4ft AnnuklS VendIon ConW Room Ara Venarson Conwtame Purge (nonsF) (2 as)

Fuel Ud vW01100"n

-C M

-0.0

'1%

90G0 ch 30000 in 26.000 dm 1.66 adm

c.

Demon rust *M re*f

-t ESF systms VW a aborl*o*y te of a samrne of fie carbon adlore, when obW nd as dtemced in ftguletoy Gsid 1.52, Revision 2, shows Me me" o AidSe penaftron Ns Ian oe v"ue specifted belo when tWed h eacor m wth ASTM 0303-190 e a tempenaure of s 30C and greater Imn or equal to the rela humkidy specled below.

E6SF VWantatSyio RH Amu4us Ven0%o

'4%

Control ROOM kM Vntgiluton 4C 0.95%

05%

AWL. Med.

F~tRed 2dWue (Nobe 1) 44%

Conftk.me Pur (nmA.F) 46%

96%

Fuel Bldg. VientitIon

<4%

96%

Not 1:

VWA.~uv 0SIV MAMO gSMMMm "IwMn woo"vs

• Ai tolu MWa ha fdt r

%ft*O Rhn nb a tiS e 063 4afb slu bsxll Mn AlD SM.10. 451 ftlM*In

fl hunol Irmling wla Sm wsat edmaskW moa rfged tudwo po ainAddniom-IOm

• o mor~ioo pu"amf -lfte f'Pw A Mow Rb lhu Sictn*UmaWd Pom

- " p,*

bh mu

.3Wim df 3 gimnp oskmwSk "W#WK&

1m=Iar W*Ovmpgi 4

l bwkbbmf,, 0IU Feiga Ihh MdisN a~bdsS 11 WMM"030 Im pqftL empof tw b *'r pfn1 IVI M ?&rtmu& bmjM Mr Caawba Unt W

and 2

&.S-13 Amenkrden Noe,

'5.

6.5 Pr mms n knl 5.5.11 Y2a2tofINrKD T

tirM 0

) (Wilnued).

d.

Oeimostve for ftch of the F syW ms that the pMwn drop easros the cmbined EPA filOm. the PM Md S

e carbon admtwb ib WeO t4Mm oe vae v

e"sclk blw hen%4 td in eordaM wti Regulaktoy u*,de 1.52, RovMo2, Wid ANSI NSO-1900 at I*flowrles SPecifed below *10M.

SF. Venilton Sysem Doa P o*st*

Am"usVAWi N

8.0in w0000cn Cotrol Room Arme VUMen S.0 in wg "0or0m Aux. Ofd. Ftered Eiiu 8.Oinom 30.000ofm Coent mftw PurWe (tortSF) (2 f6M) -

.0 in wl 25,0o0 i Fued Blg. VentMelon 0.0 in wg 16,5 dim

e.

ampnae*

t the hea for sech off Vw sOFtem fdI t the vwus sp edt below when testd n i owoordef uMl ANSI NSOtS0.4M

-E$F Vmitltlo Stinn Wellp

• 0 w Annulus Venootito 4 5#&7 IW ContrO Room Are VYAnltWn 25 26.5 kW AwL Og. FW~ etu, 40+/-4.0kW Conrainmnt Puwp (non.EgF) 120 12.0 kW Fu"l BMdg. Veasa 80 + 8/-17.3 kW The pmvfsos of OR 3.0.2 an OR &0.3 wespovbb to lie VFP trsN friuenclee DOs pogpa prvkde cwoao for poWient s ovs qg m*

tueca m~nt In One WAt One #oAd*p System, Oie quasil of radlocil contsknd In gas stoq tanks or fad Wft li tratment system, an the quent of 1

a8 contained In iuq ectod osocr quid srag tnks. The gmeo r

svity qum e eMt bede*rmwi foned wIno te nmei-Wooy n branch Tecndia Po*tion ($P) ET8 11.

'Posulated Raftcs** Release due to Was" G Sytm Look or FalW'. Tth* liu vedwea quwutl "s be dsominld In a cco1anem% 1 l Smndrd RePviw Ran, Seman ¶5.7.3, "Postuled ~adw Relemse due to Tank Flur4".

C""we Unts 1 Old 2 5.6-14

S55 15 EMOMM o-nd *#A The program shetl incude:

0.

ah ita for c eaone of qdroen awd oxygen bI the Wse Gas Holduop Sysem w

a rveftmno6 prgram ensue Ow finus we malntoad Such itb W" be qvprprs to Ow eyse's d@IWpa critra (1*., whe11 or not hw etfsym Is dclsond to w*stW a hydrogen *oumlk

b.

A suummllance progrm to *n u#W dot th quenity of radc ty contalnd in each gas soraft" n or*

at =mclsc goo sWWm tanks id fed Into fie offa bobonwit systm is lws tin f nount toi wuld res" ins ep Oos EquiMs of>

0.

6rm Wty Indyiualk imn unmstricted we. In the event of an um*b misses of dhe aWn' contn; ando C,

A survells o~s porm to aisww li fth qsantl of rsdfoe~vl conkied In al oudmor "Id wa bmt Vs OWt am not smround by Knees, dkes, or wok, capae of thoding ft tanksM W

oen and tW t do not have tnk oveftlows and srounimlng am dimls commcWd to do Liquid Radwest Tmfsent ystm i I Mn Ish f

amnt lhst would reotin %cwoenUul"o e*mdin o IbnI of 10 CFR 20, ppenidx S.

Tdb 2, Column 2 a lae fieme potable 0mr supply d

m ne st surface watw supply In an uiwetclsd ora, In ow event of an unoonolld relee f te tanks' contents.

The provisions of SR 3.0.2 amd SR 3.0.3 are appiale tb I*e Eo lemlve GOs ond Soae Ta*n'kR doMly mon g Progrm awllaen fmequew 5.5.13 Dim Fuem Oi mormn A desel fuel all teeng p wtrom tow n*p e rud te-ing o both no fuel ai and stoird fuel acll sN be Th.e pograW ahcInlud sarun SM n requireet, SM co. "n ctrall In aOM d e h appice ASTM Smndards, 1T e o

of lie pgri Isto e so

,gohefoin:

a.

Aceptaiflytof new fut oia for us pdor to addllon to ska get nuby detemkni that ow fuel oN him

1.

an A*t gmavy or en absolWt peof gaft witn mbt.

2.

a flsh pon rand OWdnemic vos*

t withi nmb for ASlM 2D fuel OlN.d Camtbe Units I nd 2

&65-15

.Amenxmmot Nms.

Progrms and Mmuul

-5.5 fom Ow _5.5'f 5.5.13 w"i CiAe i TAMn Poto (coninued)

3.

a cla and brI"t opwreom vwlh proper color or aister end

-o~m content wiVn knk

b.

Other wopories for ASTMU 2D lug all we win ftlts ifln 31 dep folowbn samP" Ord saddon IQ storae kn; Ond C.

To"l piu onoertl of lis fuel 1I is o

10 mgf when taosid every 3 dap.

The provisions of SR 3.0.2 an4 SR 3.0A3 se applicabl o fi ON"l Fuel ON Tes""n Proga tt frquence.

5.5.14 ThIs prorm provides mans for poessg change to Me Bmr of Vsne Techncal Sp-elonS.

chanso th M*us of tf TS sha be ma ndewappropils sminisaUmve, contols end review

b.

Ucensee may mute changs to aSes witou prior NRC appuovl provde Ow. cange do not requir eiwe of the Uowkbr

1.

a ca In

• oe TS ko iord* In *le cen.; or

2.

a dwnge to the updaed PAR or Bae ti requires NRC epproval purmant to 10 CFR 50.50.

c.

The Bses on~ I Program sdh ooain pwovsi to ensure dia the ams we makane conimnt withe UFSAR.

d.

Prosp c dchg utW meet the craeri of Speocadlon 5.5.14.bi or 6.5.14.b.2 above shell be reviewed and approvd by te NRC pdor to a ".o. Changes to Owe Bes mpmed wMht prior NRC approval sho be provided to Uh, NRC on a frequenwcy onm t with 10 CFR 50.71(e). wirt approved exmpons.

CaRewb Units I and 2 5.5-10 Amndmaent Mos.

Prmwrms ai bsnuem 5.6 5.5.125 This Program nsws loss of ofly ftlon Is dinected nid Nppapdat actim taken. Upon eafry kno LOO 3.0.6, an elusgn shall be madle, to I

ermie If losse of funcmtNson xis AddWondy. ~m eppropruist achs may b tsken as a result of th supfort sl m InM rabft ed WO esondg Mmoweption ato, enterin spporte system Condition and Required Acions. Thls program impleme*ts toe requkiremts of LOO 3.06. Tha $o P shW COMMin a

Prokin for cros tain derft lo e s a loss of the CpsbWty to peform doe safety hmctlon assumed In ft accident emypis dos not go unde%*4od

b.

Provss for r

the plnt Is minstAined I a sa% corndition IF mies of function cndkiin exis 10 Provsins to ensure an noperAle, sa d s ftm's Compleion Time Is not popfe extendmed a a msut of muMlt support' System hi, o amb~i wared

d.

O~w approprtae llmlteio 4 verndemtet r

PomesatOry actios.

A loss of saofey function bo ist wtek asumaing conruret hI fiure. a sa"feyfucion umed in the sacet amnlysb camnot be peufkmnd. For the purpos of th pOm, a Ios of a y funclon may exist e a support Wsyste Is kn*orsftaund:d a& A requh systerom mkra wt Io to ssm(s) sppoed by #h

b.

A lvquitd system rundom to the system(s) in n supported by#

• boperb" supported sysem Iiso iwNNWerbl or c

A rem W systm mrrade to Via sort syslems) for te supported systems (a) en (b) don is also, noperb.

The WWD Identifte *fere a Mes of sfety funtio e Nss

• f koe of safel Requked Action of theLOG in Mhchte loss of safel fUnio xists wre reqord to be ousred.

Ca ftee Units I and 2 5.5-1 menden Nlos.

Prograid MWuRIu 5.5 BRIrMs -w ME!nu al.

(connud 5.4.16 go".* saimi rboo m 3n A Control Rom Envepe (CE) H dAllty Progra n

estas and ImII mee to ensur tht WE hWbMllty Is mnfted such at, w,,h an OPSE Contol Noom Ars Vetilation syahm (CRAVS)N CRE oem"uan can control fth reacto safely under normal conditions and makdain N In a sed condion followis a ocal ont. hads chemical rle, or a smoke salenge. The ip a sha nsure Mthi aMdequte 1

0sdlon p Cobbn is provldad to pwmit acms and occupancy of we CRE wudw design bas ocoidnt (OBA) con whout monl rmcehd radlmon mpomr ln oxcos of S rem total ffoov dose quivln (TIDE) for te duraon of ge aIdet. The poram shaV l

&a 44de0, flowirg eme

a.

The definlm of the CE aid the CRE bourduy.

b. R

~equrmets fo melrsnbkni ft CRE heundsi In b des ign odi amlion

f.

u for) dsmEng a unnnsd a keko p ah OR bowmdWm bo the CRE In ws swWOe toeNO m etehods and at the 111MrlqPe1cies specilled In, Secdons CA1 and C,2 of fegAey Gulde t1.7.

Demonsatr Control Room Enelpe nMiy at duAw Pwm emctors'," Revision 0, %by 2003. and (#) nsessg CRE habably at the FRquncies sp*d in Se*ck a.1. md C.2. of Peguiety Guide 1.197.

Revision 0.

8.

earmnt, at designe batwo of he CRE pessure tlo ta eeS3W areas sosn to te CRE beondwydwt Mte 9prewbelon mode of oertplon byonetrain of Me CRAVS, cowelft at a makeup flow tab* of :S 400 oft, at a Fmquew of 18 monti an a STAGGERED EST BASIS. Theesuitsshell be banded and used as part the 18 month assesmrent of fte CRE Wuary.

e.

The quentiltatv lmits an uniltieredt ai inlekage into Ma CRE. Thea bnlts WWa be stated in a mneo to aelw dec coraum to the unwflered air isnalag measured by t %e" doe~ed in paragrp C.

The un#fAred a&W Ireakep E"i for radiological challnge Is the Inlesiag how fot asmaed i*i e tocewn bt*i aalye of OBA IoeequI s.

United air We limt for hardous ceical mot ensu Ith exposure of CR2 occupents to these haards wi be wthn ft assumpt ios IntMaecansg beass.

L. The Provisisons of $A 3.0.2 ame Sppimle t Ma 90 quances for 0ssessin CM fabity. da@tn CRE unird i6*Age, and WmUaft CRE pressure ancl asessing; Ma CRE boufluAry as requird by paragraphs (cosA enued) aihaUnits I and 2 5.5-16 Aendment Not.

Progm*

W Manuals 5.5 55Proarums and Mauals (qo*ud 6.5.17 F0m This M

oarm p e *e for

• S IAMOs FmP e*$. The pgrm gaM ens thd the SurvelMnAO P4uknmm $pa*d in ft Tedic pelfiatn ae

• pso d at komsw eufwsn to omwre the maodeim Umbn Condtms for Opeetbs aft meO

a.

The Survence Frequency ontrol Pomgram hadl cnWint ast of FrequenCis Of t ose $urwoiolmnce Irsmmnts for

~hich to Frequency Is oo*e bythe prgrm..

b.

Chwnge 10ft FRequen 00s EinftI 01SuWiWhNM FMequeny Contr Program he be mde In socOe with W 0410, A-* l

&-nwomd Method" for Cm*

of & uWnMme Fmrquene," R*evksmn 1.

C.

The prvsn of SWihtnc* Rtqutmism 3.02 aid =3 ge eppicabeo to the Fmqwuen u bwi ien he So oaflas FMuMcy Coria rogranm.

Catawbe Unts I end 2 U.-19 11IWOn Nwu.

Reportinge Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.8 Steam Generator (SG) Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of the Inspection. The report shall include:

a.

The scope of inspections performed on each SG,

b.

Degradation mechanisms found,

c.

Non-destructive examination techniques utilized for each degradation mechanism,

d.

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

e.

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

f.

The number and percentage of tubes plugged to date, and the effective plugging percentage In each steam generator,

g.

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

h.

For Unit 2, the primary to secondary LEAKAGE rate observed in each SG (if it is not practical to assign leakage to an individual SG, the entire primary to secondary LEAKAGE should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report,

i.

For Unit 2, the calculated accident leakage rate from the portion of the tubes below 14.01 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident leakage rate from the most limiting accident is less than 3.27 times the maximum primary to secondary LEAKAGE rate, the report shall describe how it was determined, and

j.

For Unit 2, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

Catawba Units I and 2 5.6-6 Amendment Nos.

SG Tube Integrity 3.4.18 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.18 Steam Generator (SG) Tube Integrity LCO 3.4.18 SG tube integrity shall be maintained.

All SG tubes satisfying the tube plugging criteria shall be plugged in accordance with the Steam Generator Program.

APPLICABILITY:

MODES 1, 2, 3, and 4.

.ACTIONS Separate Condition entry Is allowed for each SG tube.

I CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes A.1 Verify tube integrity of the 7 days satisfying the tube affected tube(s) is plugging criteria and not maintained until the next plugged in accordance refueling outage or SG with the Steam tube inspection.

Generator Program.

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

next refueling outage

-or SG tube inspection B. Required Action and B.1 Be in MODE 3.

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

B.2 Be in MODE 5.

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

I McGuire Units 1 and 2 3.4.18-1 Amendment Nos.

SG Tube Integrity 3.4.18 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.18.1 Verify SG tube integrity in accordance with the In accordance Steam Generator Program.

with the Steam Generator Program SR 3.4.18.2 Verify that each inspected SG tube that satisfies the Prior to entering tube plugging criteria is plugged in accordance with MODE 4 following the Steam Generator Program.

a SG tube inspection I

McGuire Units 1 and 2 3.4.18-2 Amendment Nos.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.8 Inservice Testina Prouram This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include the following:

a.

Testing frequencies applicable to the ASME Code for Operation and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies for Addenda terminology for performing inservice testing inservice testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less In the Inservice Testing Program for performing inservice testing activities;

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d.

Nothing in the ASME Boiler OM Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator (SG) Proaram A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident Induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

(continued)

McGuire Units 1 and 2 5.5-6 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Proaram (continued)

b.

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

1.

Structural integrity performance criterion: All In-service steam generator tubes shah retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), all anticipated transients included in the design specification, and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis In terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 0.27 gallons per minute total.

3.

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

c.

Provisions for SG tube plugging criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed.

The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which Inspection methods need to be employed and at what locations.

(continued)

McGuire Units 1 and 2 5.5-7 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG). Proram (continued)

I1. Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

2.

After the first refueling outage following SG Installation, inspect each SG at least every 72 effective full power months or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes Inspected at each scheduled Inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c, and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be Inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the Inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a) After the first refueling outage following SG Installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b) During the next 120 effective full power months, inspect 100% of the tubes.

This constitutes the second inspections period; c)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100%/o of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

3.

If crack indications are found in any SG tube, then the next Inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

(continued)

McGuire Units 1 and 2 5.5-8 Amendment No.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Steam Generator Tube Insvection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, Steam Generator (SG) Program. The report shall include:

a.

The scope of inspections performed on each SG,

b.

Degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

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

e.

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

f.

The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator, and

g.

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

(continued)

McGuire Units 1 and 2 5.6-5 Amendment Nos.

SG Tube Integrity 3.4,16 3.4.REACTOR COOLANT SYSTEM (RCS) 3.4.16 Steam Generator (SG) Tube Integrity LCO 3.4.16 SG Tube integrity shall be maintained.

All SG tubes satisfying the tube plugging criteria shall be plugged In accordance with the Steam Generator Program.

I APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS Separate Condition entry is allowed for each S(

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more SG tubes A.1 Verify tube Integrity of 7 days satisfying the tube the affected tube(s) Is plugging criteria and not maintained until the plugged in accordance next refueling outage or with the Steam 8G tube Inspection.

Generator Program.

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

tube inspection B.

Required Action and B.1 Be in MODE 3.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion lime of Condition A not AND met.

B.2 Be in MODE 5.

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

I OCONEE UNITS 1, 2. & 3 3.4.16-1 Amendment Nos. XXX, XXX, & XXX I

SG.Tube Integrity 3.4.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify SG tube integrity in accordance with In accordance with the the Steam Generator Program.

Steam Generator Program SR 3.4.16.2 Verify that each inspected SO tube that Prior to entering MODE 4 satisfies the tube plugging criteria is plugged following an SO tube in accordance with the Steam Generator inspection Program.

I

-OCONEE UNITS 1, 2. & 3 3.4.16-2 Amendment Nos. XXX, XXX, & XXX I

Programs and Manuals 5.5 5.5 Programs and Manuals-5.5.9 Inservce TeIstin Proaram (continued)

ASME Boiler and Pressure Vessel Code and applicable Addenda terminology for Inservice testing activities Weekly Monthly Quarterly or every 3 months Semiannually or every 6 months Every 9 months Yearly or annually Biennially or every 2 years Required Frequencies for performing inservice At least once per 7 days At least once per 31 days At least once per 92 days At least once per 184 days At least once per 276 days At least once per 366 days At least once per 731 days 5.5.10

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies for performing Inservice testing activities;

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d.

Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any TS.

Steam Generator (S) Proaram A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following:

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural Integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

I OCONEE UNITS 1, 2, & 3 5.0-13 Amendment Nos. XXX, XXX, & XXX I

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Steam Generator (SO) Prooram (continued)

b. Performance Criteria for SG tube Integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident Induced leakage, and operational LEAKAGE.

1. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation In the power range, hot standby, and cool down), all anticipated transients included in the design specification, and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube Integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined pdmary loads and 1.0 on axial secondary loads.

2. Accident Induced leakage performance criterion: The primary to secondary accident Induced leakage rate for any design basis accident, other than a SO tube rupture, shall not exceed the leakage rate assumed in the accident analysis In terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage Is not to exceed 150 gallons per day per SG.

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

c. Provisions for SG tube plugging criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

d. Provisions for SG tube Inspections. Periodic tube inspections shall be performed. The number and portions of the tubes inspected and methods of Inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging criteria. The tube-to-tubesheet weld Is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, Inspection methods, and inspection intervals shall be OCONEE UNITS 1, 2, & 3 5.0-14 Amendment Nos. XXX, XXX, & XXX I

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Steam Generator (SG) Proaram (continued) such as to ensure that SO tube Integrity is maintained until the next SO Inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which Inspection methods need to be employed and at what locations.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SO installation.

2. After the first refueling outage following SO installation, Inspect each SO at least every 72 effective full power months, or at least every third refueling outage (whichever results In more frequent inspections). In addition, the minimum number of tubes Inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SO inspection outages scheduled In each Inspection period as defined In a, b, c and d below.

If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the Inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SO Is scheduled to be Inspected in the Inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SO Is scheduled to be Inspected in the Inspection period.

Each inspection period defined below may be extended up to 3 effective full power months to Include a SO Inspection outage in an Inspection period and the subsequent Inspection period begins at the conclusion of the included SO inspection outage.

a) After the first refueling outage following SO Installation, Inspect 100% of the tubes during the next 144 effective full power months.

This constitutes the first inspection period; b) During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c) During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d) During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

OCONEE UNITS 1, 2, & 3 5.0-15 Amendment Nos. XXX, XXX, & XXX I

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Steam Generator (SGI Program (continued)

3. If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism j

that caused the crack Indication shal not exceed 24 effective full power months or one refueling outage (whichever results in more frequent Inspections). If definitive information, such as from examination of a I

pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like Indication is not associated with a crack(s), then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

5.5.11 Sscondan Wotr Chemisy This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation. The program shall include:

a.

Identification of a sampling schedule for the critical variables and control points for these variables;

b.

Identification of the procedures used to measure the values of the critical variables;

c.

Identification of process sampling points;

d.

Procedures for the recording and management of data;

e.

Procedures defining corrective actions for all off control point chemistry conditions; and

f.

A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which Is required to initiate corrective action.

5.5.12 Ventilation Filter Testina Proaram (VFTPU A program shall be established to implement the following required testing of filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, except that the testing specified at a frequency of 18 months Is required at a frequency of 24 months.

OCONEE UNITS 1, 2, & 3 5.0-16 Amendment Nos. XXX, XXX, & XXX I

Programs and Manuals 5.5 5.5 " Programs and Manuals 5.5.12

,ngnlation FilitS.Tesnog Prcrm (FPj (continued)

The VFTP is applicable to the Control Room Ventilation System (CRVS) Booster Fan Trains and the Spent Fuel Pool Ventilation System (SFPVS).

a.

Demonstrate, for the CRVS Booster Fan Trains, that a DOP test of the HEPA filters shows > 99.5% removal when tested In accordance with ANSI N510-1975 at the system design flow rate i 10%.

b.

Demonstrate, for the CRVS Booster Fan Trains, that a halogenated hydrocarbon test of the carbon adsorber shows >Ž99% removal when tested In accordance with ANSI N510-1975 at the system design flow rate

+/- 10%.

c.

Demonstrate, for the CRVS Booster Fan Trains and SFPVS, that a laboratory test of a sample of the carbon adsorber shows > 97.5% and 90% radioactive methyl iodide removal when tested In accordance with ASTM D3803-1 989 (300C, 95% RH), respectively.

d.

Demonstrate, for the CRVS Booster Fan Trains, that the pressure drop across the pre-fifter is *;1 in. of water and the pressure drop across the HEPA filters Is : 2 in. of water at the system design flow rate +/- 10%.

e.

Demonstrate, for the SFPVS, that a dioctyt phthalate (DOP) test of the high efficiency particulate air (HEPA) filters shows > 99% removal when tested In accordance with ANSI N510-1975 at the system design flow rate +/- 10%.

f.

Demonstrate, for the SFPVS, that a halogenated hydrocarbon test of the carbon adsorber shows Z 99% removal when tested in accordance with ANSI N510-1975 at the system design flow rate +/- 10%.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.5.13 Eosive Gas and Storaje Ta Radiacivity Monitdng Proorm This program provides controls for potentially explosive gas mixtures contained in the waste gas holdup tanks and the quantity of radioactivity contained In waste gas holdup tanks, and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks. The gaseous radioactivity quantities shall be determined. The liquid radwaste quantities shall be determined by analyzing a representative sample of the tank's contents at least once per 7 days when radioactive materials are being added to the tank.

OCONEE UNITS 1, 2, & 3 5.0-17 Amendment Nos. XXX, XXX, & XXX I

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7 Tendon Surveillance Report Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the Inspection procedures, the tolerances on cracking, and the corrective action taken.

5.6.8 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the Initial entry into MODE 4 following completion of an inspection performed In accordance with Specification 5.5.10, Steam Generator (SG) Program. The report shall include:

a.

The scope of Inspections performed on each SG,

b.

Degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

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

e.

Number of tubes plugged during the inspection outage for each j

degradation mechanism,

f.

The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator, and

g.

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

I I

IIII I I I I II OCONEE UNITS 1, 2, & 3 5.0-28 Amendment Nos. XXX, XXX, & XXX to RA-1 5-0003 RA-15-0003 Proposed Technical Specification Bases Changes (Mark-up)

(For Information Only)

SG-Tube integrity B 3.4.18' BASES APPLICABLE SAFETY ANALYSES (continued) and the main steam code safety valves until such time as the closure of these valves can be credited.

For other design basis accidents such as main steam line break, rod ejection accident, reactor coolant pump locked rotor accident, and uncontrolled rod withdrawal accident, the tubes are assumed to retain their structural Integrity (i.e., they are assumed not to rupture). The LEAKAGE Is assumed to be Initially at the limit given in LCO 3.4.13.

The three SG performance criteria and the limits included in LCO 3.4.16, "RCS Specific Activity," for DOSE EQUIVALENT 1-131 in primary coolant, and in LCO 3.7.17, 'Secondary Specific Activity,"

for DOSE EQUIVALENT 1-131 in secondary coolant, ensure the plant Is operated within its analyzed condition. The dose consequences resulting from the most limiting design basis accident are within the limits defined In GDC 19 (Ref. 2), 10 CFR 50.67 (Ref. 4), and Regulatory Guide 1.183 (Ref. 3).

SGOTube Integrity satisfies Criterion 2 of 10 CFR 50.36(c)(2)(0i).

LCO The LCO _reqius that SG tube integrity be maintained. The LCO also requires that atu.es that satiety thedrpair criteria be plugged in accordance with the Steam Generator Program.

During a SG Ion, any inspected tube that satisfies the am enerator Programmpar criteria Is removed from service l

ugging.

a t was eterm to satisfy repalicriteda but was not-plugged, the tube may still have tube integrity.

In the context of this Specification, a SG tube is defined as the entire length of the tube, including the tube wall and any repairs made to it, between the-ubeto-tubesheet weld at the tube Inlet and the tube-to-tubesheet weld at the tube outlet. The tube-to-tubesheet weld is not considered part of the tube.

A SG tube has tube integrity when it satisfies the SG performance criteria. The SG performance criteria aredefined in Specification 5.5.9, 'Steam Generator (SG) Program," and describe acceptable SG tube performance. TheSteam Generator Program also provides the evaluation process for determining conformance with the SG performance criteria.. --..

.4 :

Catawba Units I and'2 B,3.4.1'8-3.

Revision No.+-

SO Tube Integrity B 3.4.18 BASES LCO (continued) this amount would not propagate to a SO tube rupture under the stress conditions of a loss of coolant accident or a main steam fine break. If this amount of LEAKAGE is due to more than one crack, the cracks are very smal, and the above assumption is conservative.

APPLICABILITY SO tube Integrity Is challenged when the pressure differential across the tubes is large. Large differential pressures across SO tubes can only be experienced In MODES 1, 2, 3, and 4.

RCS conditions are far less challenging in MODES 5 and 6 than during MODES 1, 2, 3, and 4. In MODES 5 and 6, primary to secondary differential pressure Is low, resulting In lower stresses and reduced potential for LEAKAGE.

ACTIONS The ACTIONS are modified by a Note clarifying that the Conditions may be entered independently for each SG tube. This is acceptable because the Required Actions provide appropriate compensatory actions for each affected SO tube. Complying with the Required Actions may allow for continued operation, and subsequent affected SO tubes are governed by subsequent Condition entry and application of associated Required Actions.

Condition A applies If it is discovered that one or more SO tubes mined in an inservice Inspection satisy the tubew criteria but were not plugged in accordance with the Steam Generator Program as required by'SR 3.4.18.2. An evaluation of SO tube integrity of the affected tube(s) must be made. SO tube integrity is libaedon meeting the SO performance criteria described in the Steam Generator Program. The bGkepacdteria define limits on SO tube degradation that allow for flaw growth between inspections while still providing assurance that the SO performance criteria will continue to be met. In order to determine if a SG tube that should have been plugged has tube Integrity, an evaluation must be completed that demonstrates that the SO performance criteria will continue to be met until the next SO tube Inspection. The tube Integrity determination is based on the estimated condition of the tube at the time the situation is discovered and the estimated growth of the degradation prior to the next SO tube inspection. If it is determined that tube integrity is not being maintained, Condition B applies.

Catawba Units 1 and 2 B 3.4. 18-5 Revision No. -&-

~SG Tube :Integrity B 3.4.18 BASES ACTIONS (continued)

A Completion Time of 7 days is sufficient to complete the evaluation while minimizing the dsk of plant operation with a SG tube that may not have tube Integrity.

If the evaluation determines that the affected tube(s) have tube integrity, Required Action A.2 allows plant operation to continue until the next outage provided the Inspection interval continues to be supported by an operational assessment that reflects the affected tubes. However, the affected tube(s) must be plugged prior to entering MODE 4 following the next refueling outage or SG tube inspection. This Completion Time is acceptable since Operation until the next inspection is supported by the operational assessment.

If the Required Actions and associated Completion limes of Condition A are not met or if SG tube integrity is not being maintained, the reactor must be brought to MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and MODE 5 within 3W hours.

The allowed Completion Times are reasonable, based on operating experience, to reach the desired plant conditions from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR1 3.4.18.1 REQUIREMENTS During shutdown periods the Ss are inspected as required by this SR and the Steam Generator Program. NEI 97-06, Steam Generator Program Guidelines (Ref. 1), and its referenced EPRI Guidelines, establish the content of the Steam Generator Program. Use of the Steam Generator Program ensures that the inspection is appropriate and consistent with accepted industry practices.

During SG inspections a condition monitoring assessment of the SG tubes is performed. The condition monitoring assessment determines the 'as found' condition of the SO tubes. The purpose of. the condition monitoring assessment Is to ensure that the SG performance criteria have been met for the previous operating period.

Catawba Units 1 and 2 B 3.4.18-6 Revision No. 0

SG TubOhlntegrity.

B 3.4.18 BASES SURVEILLANCE REQUIREMENTS (continued)

The Steam Generator Program determines the scope of the c tion and the methods used to determine whether the tubes contain flaws satisfying the tubep criteria. Inspection Scope

-J(i.e., which tubes or areas of tubing within the SO are to be inspected) Is a function of existing and potential degradation locations. The Steam Generator Program also specifies the inspection methods to be used to find potential degradation.

),v 4

Inspection methods are a function of degradation morphology, 3

c-

• 4 *non-destructive examination (NDE) technique capabilities, and t.

inspection locations.

in U iro~

The Steam Generator Program defines the Frequency of SR 3.4.18.1. The Frequency Is determined In part by the operational assessment and other limits in the Steam Generator Examination Guidelines (Ref. 7). The Steam Generator Program uses information on existing degradations and growth rates to determine an inspection Frequency that provides reasonable

\\ assurance that the tubing will meet the SG performance criteria at the next scheduled inspection. In addition, Specification 5.5.9 contains prescriptive requirements concerning inspection intervals to provide added assurance that the SG performance criteria wW be met between scheduled inspections.

During a Sinspection, any inspected tube that satisfies. the Steam Generator Pr!ogspair criteria is removed from service by plugging. The tubejepeir criteria delineated In Specification

"-5.5.are ien e o ensure that tubes accepted for continued service satisfy the SG performance criteria with allowance for error in the flaw size measurement and for future flaw growth. In addition, the tubeepaIr cliteria, in conjunction with other elements of the-Stsam enerator Program, ensure that the SG performance criteria will continue to be met until the next inspection of the subject tube(s). Ref. 1 and Ref. 7 provide guidance for performing operational assessments to verify that the tubes remaining in service will continue to meet the SG performance criteria.

The Frequency of prior to entering MODE 4 following a SG tube; ins~tin ensures that the Surveillance has been completed and all tu 9 satisfying the criteria are plugged prior to s subjecting the SG tub~b to significant primary to secondary pressure differential..

Catawba Units 1 and 2 B 3.4.18-7

'Revision No.

SG Tube Integrity 83.4.18 BASES APPLICABLE The steam generator tube rupture (SGTR) accident Is the limiting design SAFETY basis event for SG tubes and avoiding an SGTR is the basis for this ANALYSES Specification. The analysis of a SGTR event assumes a bounding primary to secondary LEAKAGE rate equal to the operational LEAKAGE rate limits in LCO 3.4.13, "RCS Operational LEAKAGE," plus the leakage rate associated with a double-ended rupture of a single tube: The accident analysis for a SGTR assumes main steam isolation valve closure and cooldown via the SG safety valves or blowdown through the SG PORVs.

The analysis for design basis accidents and transients other than a SGTR assume the SG tubes retain their structural integrity (i.e., they are assumed not to rupture.) In these analyses, the steam discharge to the.

atmosphere Is based on primary to secondary leakage from any one SG of 135 gallons per day and 389 gallons per day total from all SGs. For accidents that do not involve fuel damage, the primary coolant activity level of DOSE EQUIVALENT 1.131 Is assumed to be equal to the LCO 3.4.16, "RCS Specific Activity," limits. For accidents that assume fuel damage, the primary coolant activity is a function of the amount of act"ty released from the damaged fuel. The dose consequences of these events are within the limits of GDC 19 (Ref. 2), 10 CFR 100 (Ref. 3) or the NRC approved licensing basis (e.g., a small fraction of these limits).

Steam generator tube integrity satisfies Criterion 2 of 10 CFR 50.36(c)(2)(11).

LCO The LCO requires that SG tube integrity be maintained. The LCO also requires that all SG tubes that safisfy criteria be plugged In accordance with the Steam Generator Program.

During an SG.Inspection, any inspected tube that satisfies the Steam Generator P raTmTP criteria Is removed from service by plugging. If a tube was determined to satisfy the%

criteria but was not plugged, tube may stfg have tube integrity.

In the context of this Specification, a SG tube Is defined as the entire length of the tube, including the tube wall, between the tube-to-tubesheet weld at the tube inlet and the tube-to-tubesheet weld at the tube outlet.

The tube-to-tubasheet weld is not considered part of the tube.

A SG tube has tube Integrity when it. satisfies the SG performance criteria.

The SG performance criteria are definedin Specification 5.5.9, Steam Generator Program," and describe acceptable SG tube performance.

The Steam Generator Program also'provides the evaluation process for determining conformance with the SG performance criteria.

McGuire Units I and 2 83.4.18-2 Revision No.46-McGuire Units I and 2 B83.4.18-2 Revision No.46-

.SG Tube Integrity B 3.4.18 BASES LCO (continued)

The operational LEAKAGE performance criterion provides an observable indication of SG tube conditions during plant operation. The limit on operational LEAKAGE Is contained In LCO 3.4.13, "RCS Operational LEAKAGE," and limits primary to secondary LEAKAGE through any one SG to 135 gallons per day and 389 gallons per day total through all SGs.

This limit Is based on the assumption that a single crack leaking this amount would not propagate to a SGTR under the stress conditions of a LOCA or a main steam line break. If this amount of LEAKAGE is due to more than one crack, the cracks are very small, and the above assumption is conservative.

APPLICABILITY Steam generator tube integrity is challenged when the pressure differential across the tubes Is large. Large differential pressures across SG tubes can only be experienced in MODE 1, 2, 3, or 4.

RCS conditions are far less challenging in MODES 5 and 6 than during MODES 1, 2, 3, and 4. In MODES 5 and 6, primary to secondary differential pressure is low, resulting in lower stresses and reduced potential for LEAKAGE.

ACTIONS The ACTIONS are modified by a Note clarifying that the Conditions may be entered independently for each SO tube. This Is acceptable because the Required Actions provide appropriate compensatory actions for each affected SG tube. Complying with the Required Actions may allow for continued operation, and subsequent affected SG tubes are governed by subsequent Condition entry and application of associated Required Actions..

A.1 nd.A.2 Condition A applies if it is discovered that one or more SG tubes examined in an inservice Inspection satisty the t criteria but were.

plugged in accordance with the Stear Generator Program as required by SR 3.4.1$.2. An evaluation of SG tube integrity of the affected tube(s) must be made. Steam generator tube integrity is based on meeting the SG performance critera described In the Steam Generator Program. The q criteria define limits on SG tube Fde:radation that allow Vor flaw growth between inspections while still providing assurance that the SG performance criteria will continue to be met. In order to determine if a SG tube that should have been plugged has tube Integrity, an evaluation must be completed that demonstrates that the SG performance criteria will continue to be met until the next refueling outage or SG tube inspection, which ever is shorter. The tube integrity determination is based on the estimated condition of the tube at the time the situation is discovered and the estimated growth of the degradation prior to the next SG tube inspection. If it is determined that tube integrity is not being maintained, Condition B applies.

• Mcuir UntsI In 2

I34.8-IRvsin oI6

.McGu.re Units and 2

-8.3.4. 1-"

Revision No. 4*-

SG Tube Integrity ri(9 83.4.18 BASES Actions (continued)

A Completion Time of 7 days Is sufficient to complete the evaluation while minimizing the risk of plant operation with a SO tube that may not have tube integrity.

If the evaluation determines that the affected tube(s) have tube integrity, Required Action A.2 allows plant operation to continue until the next refueling outage or SG inspection provided the inspection Interval continues to be supported by an operational assessment that reflects the affected tubes. However, the affected tube(s) must be plugged prior to entering MODE 4 following the next refueling outage or SG Inspection.

This Completion Time is acceptable since operation until the next inspection is supported by the operational assessment.

[1. 10 B If the Required Actions and associated Completion Times of Condition A are not met or If SO tube integrity is not being maintained, the reactor must be brought to MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

The allowed Completion Times are reasonable, based on operating experience, to reach the desired plant conditions from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SiA..16.1 REQUIREMENTS During shutdown periods the SGs are inspected as required by this SR and the Steam Generator Program. NEI 97-06, Steam Generator Program Guidelines (Ref. t), and its referenced EPRI Guidelines, establish the content of the Steam Generator Program. Use of the Steam Generator Program ensures that the inspection is appropriate and consistent with accepted industry practices.

During SG inspections a condition monitoring assessment of the SG tubes is performed. The condition monitoring assessment determines the "as foundW condition of the SG tubes. The purpose of the condition monitoring assessment is to ensure that the SG performance criteria have been met for; the previous operating period..

cuIrI UIt III I

andI II 2I 3

185 eIsion No8 McGuire Units 1 and 2 8 3.4.18-5 Revision No. 86

SO Tube integrity 8 3.4.18 BASES SURVEILLANCE REQUIREMENTS (continued)

The Steam Generator Program determines the scope of the inspection and the methods used to determine whether the tubes contain flaws sati the tul:

e criteria. Inspection scope (i.e., which tubes or areas of tubing within the SG are to be inspected) is a function of existing and potential degradation locations. The Steam Generator Program also specifies the inspection methods to be used to find potential degradation.

Inspection methods are a function of degradation morphology, non-destructive examination (NDE) technique capabilities, and Inspection locations.

vi The Steam Generator Program defines the Frequency of SR 3.4.18.1.

INC, The Frequency is determined by the operational assessment and other S..*

-limits in the SG examination guidelines (Ref. 6). The Steam-Generator

' " Program uses information on existing degradations and growth rates to determine an Inspection Frequency that provides reasonable assurance that the tubing will meet the SO performance criteria at the next

,scheduled inspection. In addition, Specification 5.5.9 contains S _

prescriptive requirements concerning inspection intervals to provide 0-added assurance that the SG Performance criteria will be met between

,E scheduled inspections Sw During an SG inspection, any Insected tube that satisfies the Steam

< -4

'1 Generator P ram m crit. eria is removed from service bv plynino.

V q,-, 4z 2' The tube mpetriterla delineated in Specification 5.5.9 are intended to

• -1*

4 ensure that tubes accepted for continued service satisfy the SG performance criteria with allowance for error In the flaw size L

measurement and for future flaw growth. In addition, the tube mpe.&

criteria, in conjunction with other elements of the Steam Generator

JProgram, ensure that the SG performance criteria will continue to be met until the next Inspection of the subject tube(s). Reference 1 provides guidance for performing operational assessments to verify that the tubes remaining in service will continue to meet the SO performance criteria.

The Frequency of prior to entering MODE 4 following a SO inspection ensures that the Surveillance has been completed and all tubes meeting thopeWs criteria are plugged prior to subjecting the SO tubes to significant primary to secondary pressure differential.'

.')

4F e I

_I" Jill Jnisl ad I3I4.I184 ReIso No I

McGuire Units I and 2 "

B 3.4.18-6 Revision No.

SG Tube Integrity B 3.4.16 BASES APPLICABLE The steam generator tube rupture (SGTR) accident is the limiting design SAFETY basis event for SG tubes and avoiding an SGTR is the basis for this ANALYSES Specification. The analysis of a SGTR event assumes a bounding primary to secondary LEAKAGE rate equal to the operational LEAKAGE rate limits In LCO. 3.4.13, *RCS Operational LEAKAGE," plus the leakage rate associated with a double-ended rupture of a single tube. The accident analysis for a SGTR assumes cooldown via the main steam atmosphere dump valves.

The analysis for design basis accidents and transients other than a SGTR assume the SG tubes retain their structural integrity (i.e., they are assumed not to rupture.) In these analyses, the steam discharge to the atmosphere bounds the primary to secondary LEAKAGE of 150 gallons per day per SG. For accidents that do not involve fuel damage, the primary coolant activity level of DOSE EQUIVALENT 1-131 Is assumed to be equal to the LCO 3.4.16, "RCS Specific Activity," limits. For accidents that assume fuel damage, the pdmary coolant activity Is a function of the amount of activity released from the damaged fuel. The dose consequences of these events are within the limits of GDC 19 (Ref. 2), 10 CFR 100 (Ref. 3) or the NRC approved licensing basis (e.g., a small fraction of these limits).

Steam generator tube integrity satisfies Criterion 2 of 10 CFR 50.36(c)(2)(i).

LCO The LCO requires that SG tube integrity be maintained. The LCO also requires that all SG tubes that satis tepi criteria be plugged in accordance with the Steam Generator Program.

During an SG inspection, any Inspected tube that satisfies the Steam Generator Programj criteria is removed from servce by plugging. If a ule was oemled to satisfy th jepr criteria but was not plugged,

-thetb may su aetube integrity.

In the context of this Specification, a SG tube is defined as the entire length of the tube, Including the tube wall, between the tube-to-tubesheet weld at the tube inlet and the tube-to-tubesheet weld at the tube outlet.

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

A SG tube has tube integrity when it satisfies the SG performance criteria.

The SG performance. criteria are defined-in Specification 5.510'" Steam Generator Program," and describe acceptable SG tube performance.

The Steam Generator Program also provides the evaluation process for determining conformance with the SG performance criteria.

OCONEE UNITS 1, 2, & 3 B 3.4.16-2 Amendment Nos. 355,3857", &-3 I

SG Tube Integrity B 3.4.16 I BASES LCO (continued)

The operational LEAKAGE performance criterion provides an observable indication of SG tube conditions during plant operation. The limit on operational LEAKAGE Is contained In LCO 3.4.13, "RCS Operational LEAKAGE," and limits pdmary to secondary LEAKAGE through any one SG to 150 gallons per day. This limit is based on the assumption that a single crack leaking this amount would not propagate to a SGTR under the stress conditions of a LOCA or a main steam line break. If this amount of LEAKAGE Is due to more than one crack, the cracks are very small, and the above assumption is conservative.

APPLICABILITY Steam generator tube integrity is challenged when the pressure differential across the tubes Is large. Large differential pressures across SG tubes can only be experienced in MODE 1, 2, 3, or 4.

RCS conditions are far less challenging in MODES 5 and 6 than during MODES 1, 2, 3, and 4. In MODES 5 and 6, primary to secondary differential pressure Is low, resulting In lower stresses and reduced potential for LEAKAGE.

ACTIONS The ACTIONS are modified by a Note clarifying that the Conditions may be entered Independently for each SG tube. This is acceptable because the Required Actions provide appropriate compensatory actions for each affected SG tube. Complying with the Required Actions may allow for continued operation, and subsequent affected SG tubes are governed by subsequent Condition entry and application of associated Required Actions.

Condition A applies if it Is discovered that one or more SG tubes examined in an inservice Inspection satisfy the riteria but were not plugged in accordance with the Steam tor Program as required by SR 3.4.16.2. An evaluation of SG tube integrity of the affected tube(s) must be made. Steam generator tube integrity is based on meeting the SO performance criteria described in the Steam Generator Poram. The S%

ap criteria define limits on SG tube Ldegradation that allow for flaw growth between Inspections while still providing assurance that the SG performance criteria will continue to be met. In order to determine If a SG tube that should have been plugged has tube Integrity, an evaluation must be completed that demonstrates that the SG performance criteria will continue to be met until the next refueling outage or SG tube Inspection, which ever is shorter. The tube Integrity determination is based on the estimated condition of the tube at the time the situation Is discovered and the estimated growth of the degradation prior to the next SG tube inspection. If it Is determined that tube integrity is not being maintained, Condition B applies.

OCONEE UNITS 1, 2, & 3 8 3.4.16-4 Amendment Nos. 356, 367;, & -058-, I

SG Tube Integrity B 3.4.16 1 BASES SURVEILLANCE REQUIREMENTS SR 3.4.16.1 (continued)

The Steam Generator Program determines the scope of the inspection and the methods used to determine whether the tubes contain flaws satisfying the ty criteria. Inspection scope (i.e., which tubes or areas of tubing within the SG are to be inspected) is a function of existing and potential degradation locations. The Steam Generator Program also specifies the inspection methods to be used to find potential degradation.

Inspection methods are a function of degradation morphology, non-destructive examination (NlDE) technique capabiities, and inspection

- i7* locations.

The Steam Generator Program defines the Frequency of SR 3.4.16.1.

S-4 y

The Frequency Is determined by the operational assessment and other r ",

limits in the SG examination guidelines (Ref. 6). The Steam Generator t *.-.

Program uses information on existing degradations and growth rates to

. Y C) determine an Inspection Frequency that provides reasonable assurance I

that the tubing will meet the SG performance criteria at the next S

v scheduled inspection. In addition, Specification 5.5.10 contains

~ ~prescriptive requirements concerning inspection intervals to provide added assurance that the SG performance criteria will be met between 4

.~-

scheduled inspectioins.6 nerator Program efita Is removed from service by plugging.

u tube fs criteria delineatedIn afhftmS M *lt":ded to re that tubes accepted for continued swaxice satisfy the SG rforancecriteria with allowance for error In the flaw size surement and for future flaw growth. In addition, the tube repair criteria, in conjunction with other elements of the Steam Generator Program, ensure that the SO performance criteria will continue to be met until the next inspection of the subject tube(s). Reference 1 provides guidance for performing operational assessments to verify that the tubes remaining In service will continue to meet the SG performance criteria.

The Frequency of prior to entering MODE 4 following a SG inspection ensures that the Surveillance has been completed and all tubes meeting th criteria are plugged prior to subjecting the SG tubes to gnlflcant primary to secondary pressure differential.

7

='

(C S -sr, ý.

}

)

OCONEE UNITS 1, 2, & 3 B 3.4.16-6 Amendment Nos.,

.,", &,," I