Text

Application to Revise Technical Specifications to Adopt TSTF-545, Revision 3, TS Inservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing
	ML17312A362
Person / Time
Site:	Oconee, Catawba, Harris, Robinson, McGuire
Issue date:	11/07/2017
From:	Henderson K; Duke Energy Progress
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	RA-17-0005
	Download: ML17312A362 (153)
	v • d • e

{{#Wiki_filter:( DUKE "' ENERGY~ Serial: RA-17-0005 November 7, 2017 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 CATAWBA NUCLEAR STATION, UNITS 1 AND 2 KELVIN HENDERSON Senior Vice President Nuclear Corporate 526 S. Church Street, EC-07H Charlotte, NC 28202 980-373-1295 Kelvin. Henderson@duke-energy.com 10 CFR 50.90 DOCKET NOS. 50-413 AND 50-414 / RENEWED LICENSE NOS. NPF-35 AND NPF-52 MCGUIRE NUCLEAR STATION, UNITS 1 AND 2 DOCKET NOS. 50-369 AND 50-370 I RENEWED LICENSE NOS. NPF-9 AND NPF-17 OCONEE NUCLEAR STATION, UNIT NOS. 1, 2 AND 3 DOCKET NOS. 50-269, 50-270 AND 50-287 I RENEWED LICENSE NOS. DPR-38, DPR-47 AND DPR-55 SHEARON HARRIS NUCLEAR POWER PLANT, UNIT NO. 1 DOCKET NO. 50-400 I RENEWED LICENSE NO. NPF-63 H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 DOCKET NO. 50-261 I RENEWED LICENSE NO. DPR-23

SUBJECT:

APPLICATION TO REVISE TECHNICAL SPECIFICATIONS TO ADOPT TSTF-545, REVISION 3, "TS INSERVICE TESTING PROGRAM REMOVAL & CLARIFY SR USAGE RULE APPLICATION TO SECTION 5.5 TESTING" Pursuant to 10 CFR 50.90, Duke Energy Progress, LLC, and Duke Energy Carolinas, LLC, collectively referred to henceforth as "Duke Energy," is submitting a request for amendments to the Technical Specifications (TS) for Catawba Nuclear Station (CNS), Units 1 and 2; McGuire Nuclear Station (MNS), Units 1 and 2; Oconee Nuclear Station (ONS), Units 1, 2 and 3; Shearon Harris Nuclear Power Plant (HNP), Unit 1; and H. B. Robinson Steam Electric Plant (RNP), Unit No. 2. The proposed change would modify TS requirements regarding inservice testing. This request is consistent with NRG-approved Technical Specifications Task Force (TSTF) Traveler TSTF-545, Revision 3, "TS lnservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing." provides a description and assessment of the proposed change. Attachment 2 provides the existing TS pages marked up to show the proposed change. Attachment 3 provides existing TS Bases pages marked up to show the proposed change. Changes to the existing TS Bases will be implemented under the Technical Specification Bases Control

U.S. Nuclear Regulatory Commission RA-17-0005 Page2 Program. They are provided in Attachment 3 for information only. The retyped TS pages will be provided to the NRC immediately prior to issuance of the approved amendments. The proposed change has 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 change involves no significant hazards consideration. The bases for these determinations are included in. This submittal contains no regulatory commitments. Duke Energy requests approval of the proposed change by November 7, 2018. Once approved, the amendments will be implemented within 120 days. In accordance with 1 O CFR 50.91, a copy of this application, with Attachments, is being provided to the designated North Carolina and South Carolina officials. If you shouJd have any questions regarding this submittal, or require additional information, please contact Art Zaremba, Manager-Nuclear Fleet Licensing, at (980)373-2062. I declare under penalty of perjury that the foregoing is true and correct. Executed on November 7, 2017.

ft2--

Kelvin Henderson Senior Vice President - Nuclear Corporate JLV Attachments: 1. Description and Assessment of Technical Specifications Changes

2. Proposed Technical Specification Changes (Mark-up)

3. Proposed Technical Specification Bases Changes (Mark-up)- For Information Only

U.S. Nuclear Regulatory Commission RA-17-0005 Page 3 cc (with Attachments): C. Haney, USNRC Region II - Regional Administrator J. D. Austin, USNRC Senior Resident Inspector - CNS G. A. Hutto, USNRC Senior Resident Inspector - MNS D. Retterer, USNRC Senior Resident Inspector - HNP J. Rotton, USNRC Senior Resident Inspector-RNP E. L. Crowe, USN RC Senior Resident Inspector - ONS M. C. Barillas, NRR Project Manager - HNP D. Galvin, NRR Project Manager - RNP M. Mahoney, NRR Project Manager-CNS and MNS A. L. Klett, NRR Project Manager - ONS A. Gantt, Chief, Bureau of Radiological Health (SC) A. Wilson, Attorney General (SC) ~---- -- W. L. Cox, 111, Section Chief, North Carolina Department of Health and Human Services, RP Section (NC) S. E. Jenkins, Manager, Radioactive and Infectious Waste Management (SC) to RA-17-0005 Page 1 of 7 Description and Assessment of Technical Specifications Changes

Subject:

Application to Revise Technical Specifications to Adopt TSTF-545, Revision 3, "TS lnservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing"

1.0 DESCRIPTION

2.0 ASSESSMENT

2.1 Applicability of Published Safety Evaluation 2.2 Variations

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Analysis 4.0 ENVIRONMENTAL EVALUATION to RA-17-0005 Page 2 of 7

1.0 DESCRIPTION

The proposed change affects the Technical Specifications (TS) for Catawba Nuclear Station (CNS), Units 1 and 2; McGuire Nuclear Station (MNS), Units 1 and 2; Oconee Nuclear Station (ONS), Units 1, 2 and 3; Shearon Harris Nuclear Power Plant (HNP), Unit 1; and H. B. Robinson Steam Electric Plant (RNP), Unit No. 2. The proposed change eliminates the "lnservice Testing Program" from Technical Specification (TS) Section 5.5 (TS Section 6.8.4 for HNP}, removing requirements duplicated in American Society of Mechanical Engineers (ASME) Code for Operations and Maintenance of Nuclear Power Plants (OM Code), Case OMN-20, "lnservice Test Frequency." A new defined term, "lnservice Testing Program," is added to TS Section 1.1 (TS Section 1.0 for HNP}, "Definitions." The proposed change to the TS is consistent with TSTF-545, Revision 3, TS lnservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing."

2.0 ASSESSMENT

2.1 Applicability of Published Safety Evaluation Duke Energy has reviewed the model safety evaluation provided to the Technical Specifications Task Force in a letter dated December 11, 2015 (NRC ADAMS Accession Nos. ML15314A365 and ML15314A305). This review included a review of the NRC staff's evaluation, as well as the information provided in TSTF-545. Duke Energy has concluded that the justifications presented in TSTF-545, and the model safety evaluation prepared by the NRC staff are applicable to CNS, MNS, ONS, HNP, and RNP, and justify this amendment for the incorporation of the changes to each plant's TS. CNS was issued a construction permit on August 7, 1975 and the provisions of 10 CFR 50.55a(f)(3) are applicable. MNS was issued a construction permit on February 28, 1973 and the provisions of 10 CFR 50.55a(f)(2) are applicable. ONS was issued a construction permit on November 6, 1967 and the provisions of 10 CFR 50.55a(f)(1) are applicable. HNP was issued a construction permit on January 27, 1978 and the provisions of 10 CFR 50.55a(f)(3) are applicable. RNP was issued a construction permit on April 13, 1967 and the provisions of 10 CFR 50.55a(f)(1) are applicable. 2.2 Variations Duke Energy is proposing the following variations from the TS changes described in TSTF-545. These differences are administrative and do not affect the applicability of TSTF-545 or the NRC staffs model safety evaluation to the proposed license amendment. General TSTF-545 eliminates the "lnservice Testing Program" from Standard TS Technical Specification (STS) Section 5.5, and renumbers subsequent sections of STS Section 5.5 accordingly. So as to eliminate administrative changes associated with deleting the lnservice Testing Program Section and renumbering numerous subsequent TS sections, the proposed change retains the header for the lnservice Testing Program Section, while replacing the content of the section with a Note that refers to the TS Definitions section for the definition of INSERVICE TESTING PROGRAM. By retaining the current program numbering and including the note, excessive administrative burden is avoided. to RA-17-0005 Page 3 of 7 The TSTF-545 changes to the NUREG-1430 and NUREG-1431 markups for STS Limiting Condition for Operation (LCO) 3.0.6 are related to the renumbering of STS Section 5.5. As noted above, the proposed change does not include this renumbering. Hence, the TSTF-545 changes related to STS LCO 3.0.6 do not apply. The TSTF-545 changes to the NUREG-1431 markups for STS Surveillance Requirement (SR) 3.4.10.1 include capitalization of the term "lnservice Testing Program" in the "Frequency" column, but neglect to include capitalization of the same term in the "Surveillance" column. The proposed change for CNS, MNS, and RNP corrects this oversight by including capitalization of the term in both instances. Catawba TSTF-545 includes different markups for STS 3.6.6, depending upon which containment type applies. The CNS containment is of an ice condenser design; hence, the NUREG-1431 STS 3.6.6C markup included in TSTF-545 applies, and the STS 3.6.6A, 3.6.68, 3.6.60, and 3.6.6E markups do not apply. The CNS SR corresponding to STS 3.6.6C.2 is SR 3.6.6.2, and the proposed change includes this CNS SR in the scope. TSTF-545 includes a NUREG-1431 markup for SR 3.6.12.1 of STS TS 3.6.12, "Vacuum Relief Valves." CNS has no corresponding TS. Therefore, this portion of TSTF-545 is not applicable to CNS. McGuire TSTF-545 includes different markups for STS 3.6.6, depending upon which containment type applies. The MNS containment is of an ice condenser design; hence, the NUREG-1431 STS 3.6.6C markup included in TSTF-545 applies, and the STS 3.6.6A, 3.6.68, 3.6.60, and 3.6.6E markups do not apply. The MNS SR corresponding to STS 3.6.6C.2 is SR 3.6.6.2, and the proposed change includes this MNS SR in the scope. TSTF-545 includes a NUREG-1431 markup for SR 3.6.12.1 of STS TS 3.6.12, "Vacuum Relief Valves." MNS has no corresponding TS. Therefore, this portion of TSTF-545 is not applicable to MNS. Oconee TSTF-545 includes a NUREG-1430 markup for SR 3.4.14.1. The corresponding ONS TS SR 3.4.14.1 does not include a reference to the lnservice Testing Program. Therefore, this portion of TSTF-545 is not applicable to ONS. TSTF-545 includes a NUREG-1430 markups for SR 3.5.2.4. The corresponding portions of the ONS TS are SR 3.5.2.3 and SR 3.5.3.3. TSTF-545 includes NUREG-1430 markups for SR 3.6.3.5, SR 3.6.6.4, and TS 5.5.8. The corresponding portions of the ONS TS are SR 3.6.3.4, SR 3.6.5.3, and TS 5.5.9, respectively. TSTF-545 includes a NUREG-1430 markup for SR 3.7.2.1 regarding Main Steam Isolation Valves (MSIVs). ONS design has no corresponding TS. Therefore, this portion of TSTF-545 is not applicable to ONS. ONS TS 3.7.10, "Protected Service Water (PSW) System", includes SRs 3.7.10.3, 3.7.10.8, and 3.7.10.10, which all reference the lnservice Testing Program. Although there is not a corresponding TS in NUREG-1430, the proposed change includes changes to SR 3.7.10.3, SR 3.7.10.8, and SR 3.7.10.10 to make "lnservice Testing to RA-17-0005 Page 4 of 7 Program" all capital letters. This portion of the proposed change is consistent with changes to other SRs included in the scope of TSTF-545. ONS TS 3.7.19, "Spent Fuel Pool Cooling (SFPC) Purification System Isolation from Borated Water Storage Tank (BWST)", includes LCO 3.7.19, SR 3.7.19.2, and SR 3.7.19.3, which all reference the lnservice Testing Program. Although there is not a corresponding TS in NUREG-1430, the proposed change includes changes to LCO 3.7.19, SR 3.7.19.2, and SR 3.7.19.3 to make "lnservice Testing Program" all capital letters. This portion of the proposed change is consistent with changes to other SRs included in the scope of TSTF-545. ONS TS 3.10.1, "Standby Shutdown Facility," includes SRs 3.10.1.14 and 3.10.1.15, which both reference the lnservice Testing Program. Although there is not a corresponding TS in NUREG-1430, the proposed change includes changes to SR 3.10.1.14 and SR 3.10.1.15 to make "lnservice Testing Program" all capital letters. This portion of the proposed change is consistent with changes to other SRs included in the scope of TSTF-545. HNP has not converted to the NUREG-1431 improved Standard Technical Specifications (STS). Therefore, the general format and numbering convention associated with the current TS has been retained. In particular, individual defined terms listed in TS Section 1.0 have unique numbers in the HNP TS, whereas in the STS, they do not. Therefore the new defined term, "INSERVICE TESTING PROGRAM," will be designated as TS 1.17a. Associated with this change, the HNP TS Index, page i, is revised to add the new TS 1.17a. TSTF-545 includes NUREG-1431 markups for SR 3.4.10.1, SR 3.5.2.4, SR 3.6.3.5, SR 3.6.12.1, SR 3.7.1.1, SR 3.7.2.1, and TS 5.5.8. The corresponding portions of the HNP TS are SR 4.4.2.1, SR 4.4.2.2, SR 4.5.2.f, SR 4.6.3.3, SR 4.6.5, SR 4.7.1.1, SR 4.7.1.5, and TS 6.8.4.m. TSTF-545 includes a NUREG-1431 markup for SR 3.4.14.1 regarding Reactor Coolant System (RCS) Pressure Isolation Valve (PIV) leakage. The corresponding HNP SR is SR 4.4.6.2.2. However, this SR does not include a reference to the lnservice Testing Program. Therefore, this portion of TSTF-545 is not applicable to HNP. TSTF-545 includes different markups for STS 3.6.6, depending upon which containment type applies. The HNP containment is an atmospheric design, with credit taken for iodine removal by the containment spray system; hence, the NUREG-1431 STS 3.6.6A markup included in TSTF-545, specifically SR 3.6.6A.4, is most applicable, and the STS 3.6.68, 3.6.6C, 3.6.60, and 3.6.6E markups do not apply. The HNP SR corresponding to STS 3.6.6A.4 is SR 4.6.2.1.b, and the proposed change includes this HNP SR in the scope. TSTF-545 includes a NUREG-1431 markup for SR 3.7.3.1 regarding Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs). The HNP TS do not include a corresponding SR. Therefore, this portion of TSTF-545 is not applicable to HNP. TSTF-545 includes a NUREG-1431 markup for SR 3.7.5.2 regarding Auxiliary Feedwater Pump developed head. The corresponding HNP SR 4.7.1.2.1.a does not include a reference-to the lnservice Testing Program. Therefore, this portion of TSTF-545 is not applicable to HNP. HNP TSs include SR 4.1.2.3.1, SR 4.1.2.4, SR 4.4.4.1, and SR 4.7.13.a, each of which references the lnservice Testing Program. Although there is not corresponding TS SRs to RA-17-0005 Page 5 of 7 in NUREG-1431, the proposed change includes changes to these HNP SRs to make "lnservice Testing Program" all capital letters. This portion of the proposed change is consistent with changes to other SRs included in the scope of TSTF-545. Robinson TSTF-545 includes NUREG-1431 markups for SR 3.5.2.4, SR 3.6.3.5, and SR 3.7.3.1. The corresponding portions of the RNP TS are SR 3.5.2.3, SR 3.6.3.4, and SR 3.7.3.1/SR 3.7.3.2, respectively. TSTF-545 includes different markups for STS 3.6.6, depending upon which containment type applies. The RNP containment is an atmospheric design, with credit taken for iodine removal by the containment spray system; hence, the NUREG-1431 STS 3.6.6A markup included in TSTF-545, specifically SR 3.6.6A.4, is most applicable, and the STS 3.6.68, 3.6.6C, 3.6.6D, and 3.6.6E markups do not apply. The RNP SR corresponding to STS 3.6.6A.4 is SR 3.6.6.4, and the proposed change includes this RNP SR in the scope. TSTF-545 includes a NUREG-1431 markup for SR 3.6.12.1 of STS TS 3.6.12, "Vacuum Relief Valves." RNP has no corresponding TS. Therefore, this portion of TSTF-545 is not applicable to RNP. TSTF-545 includes a NUREG-1431 markup for SR 3.7.5.2 regarding Auxiliary Feedwater Pump developed head. The corresponding RNP SR 3.7.4.2 does not include a reference to the lnservice Testing Program. Therefore, this portion of TSTF-545 is not applicable to RNP. RNP TSs include SR 3.6.8.3 regarding the Isolation Valve Seal Water System, which references the lnservice Testing Program. There is not a corresponding TS SR in NUREG-1431. However, the proposed change includes a change to RNP SR 3.6.8.3 to make "lnservice Testing Program" all capital letters. This portion of the proposed change is consistent with changes to other SRs included in the scope of TSTF-545.

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Analysis Duke Energy requests adoption of the Technical Specification (TS) changes described in TSTF-545, "TS lnservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing," which is an approved change to the improved Standard Technical Specifications (STS), into the Catawba Nuclear Station (CNS), Units 1 and 2, McGuire Nuclear Station, Units 1 and 2 (MNS), Oconee Nuclear Station (ONS), Units 1, 2 and 3, Shearon Harris Nuclear Power Plant (HNP), Unit No. 1, and H. B. Robinson Steam Electric Plant (RNP), Unit No. 2 Technical Specifications. The proposed change revises the TS Chapter 5 (TS Chapter 6 for HNP), "Administrative Controls," Section 5.5 (Section 6.8.4 for HNP), "Programs and Manuals," to replace the current contents of the "lnservice Testing (IST) Program" specification with a note referring to the TS Definition of "INSERVICE TESTING PROGRAM". Requirements in the IST Program are removed, as they are duplicative of requirements in the American Society of Mechanical Engineers (ASME) Operations and Maintenance (OM) Code, as clarified by Code Case OMN-20, "lnservice Test Frequency." Other requirements in Section 5.5 (Section 6.8.4 for HNP) are eliminated because the Nuclear Regulatory Commission (NRC) has determined their appearance in the TS is contrary to regulations. A new defined term, "INSERVICE TESTING PROGRAM," is added, which references the requirements of Title 10 of the Code of Federal Regulations (1 O CFR), Part 50, paragraph 50.55a(f). to RA-17-0005 Page 6 of 7 Duke Energy has evaluated whether or not a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed 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 TS Chapter 5 (TS Chapter 6 for HNP), "Administrative Controls," Section 5.5 (Section 6.8.4 for HNP), "Programs and Manuals," by replacing the current contents of the "lnservice Testing Program" specification with a note referring to the TS Definition of "INSERVICE TESTING PROGRAM". Most requirements in the lnservice Testing Program are removed, as they are duplicative of requirements in the ASME OM Code, as clarified by Code Case OMN-20, "lnservice Test Frequency." The remaining requirements in the Section 5.5 (Section 6.8.4 for HNP) IST Program are eliminated because the NRC has determined their inclusion in the TS is contrary to regulations. A new defined term, "INSERVICE TESTING PROGRAM," is added to the TS, which references the requirements of 10 CFR 50.55a(f). Performance of inservice testing is not an initiator to any accident previously evaluated. As a result, the probability of occurrence of an accident is not significantly affected by the proposed change. lnservice test frequencies under Code Case OMN-20 are equivalent to the current testing period allowed by the TS with the exception that testing frequencies greater than or equal to 2 years may be extended by up to 6 months to facilitate test scheduling and consideration of plant operating conditions that may not be suitable for performance of the required testing. The testing frequency extension will not affect the ability of the components to mitigate any accident previously evaluated as the components are required to be operable during the testing period extension. Performance of inservice tests utilizing the allowances in OMN-20 will not significantly affect the reliability of the tested components. As a result, the availability of the affected components, as well as their ability to mitigate the consequences of accidents previously evaluated, is not affected. Therefore, the proposed 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 change does not alter the design or configuration of the plant. The proposed change does not involve a physical alteration of the plant; no new or different kind of equipment will be installed. The proposed change does not alter the types of inservice testing performed. In most cases, the frequency of inservice testing is unchanged. However, the frequency of testing would not result in a new or different kind of accident from any previously evaluated since the testing methods are not altered. Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated. to RA-17-0005 Page 7 of 7

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

Response: No. The proposed change eliminates some requirements from the TS in lieu of requirements in the ASME Code, as modified by use of Code Case OMN-20. Compliance with the ASME Code is required by 10 CFR 50.55a. The proposed change also allows inservice tests with frequencies greater than or equal to 2 years to be extended by 6 months to facilitate test scheduling and consideration of plant operating conditions that may not be suitable for performance of the required testing. The testing frequency extension will not affect the ability of the components to respond to an accident as the components are required to be operable during the testing period extension. The proposed change will eliminate the existing TS SR 3.0.3 allowance to defer performance of missed inservice tests up to the duration of the specified testing frequency, and instead will require an assessment of the missed test on equipment operability. This assessment will consider the effect on a margin of safety (equipment operability). Should the component be inoperable, the Technical Specifications provide actions to ensure that the margin of safety is protected. The proposed change also eliminates a statement that nothing in the ASME Code should be construed to supersede the requirements of any TS. The NRC has determined that statement to be incorrect. However, elimination of the statement will have no effect on plant operation or safety. Therefore, 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 effluents 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-17-0005 Proposed Technical Specification Changes (Mark-up)

1.1 Definitions (continued) DOSE EQUIVALENT Xe-133 ENGINEERED SAFETY FCATURE{ESF)RESPONSE TIME I ~SEJ!.V I C,,t /EST nJG P /.Ob fl.Al/I Catawba Units 1 and 2 Definitions 1.1 DOSE EQUIVALENT Xe-133 shall be that concentration of Xe-133 {microcuries per gram) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-85, Kr-87, Kr-88, Xe-131m, xe.. 133m, Xe-133, Xe-135m, Xe-135, and Xe-138 actually present. If a specific noble gas nuclide is not detected, it should be assumed to be present at the minimum detectable activity. The determination of DOSE EQUIVALENT Xe-133 shall be performed using effective dose conversion factors for air submersion listed in Table 111.1 of EPA Federal Guidance Report No. 12, 1993, "External Exposure to Radionuclides in Air, Water, and Soil." The ESF RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and the methodology for verification have been previously reviewed and approved by the NRC. /Cu_ I 1'.JJelJJ I~ n;-sTIO (., f> U;>&,._A~ i -' -{1lv.- { j c.. t:vr He:. f ~j r11...v '1U,. -f- {VI f I ( i.J -ffie-r-e 7 v,"r..,...,~tt+s. ~.f-10 c..FI-so. SSa. (+). (continued) 1.1-3 Amendment Nos. a&liQS4-

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.10.1 Catawba Units 1 and 2 3.4.10-2 Pressurizer Safety Valves 3.4.10 FREQUENCY Amendment Nos. f7311e~

SURVEILLANCE REQUIREMENTS SR 3.4.14.1 SURVEILLANCE

NOTES,----------_.--

1.

Not required to be performed in MODES 3 and 4.

2.

Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3.

RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided. Verify leakage from each RCS PIV is equivalent to~ 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure?. 2215 psig and ~ 2255 psig. RCS PIV Leakage 3.4.14 FREQUENCY Prior to entering MODE2 whenever the unit has been in MODE 5for 7 days or more, if leakage testing has not been performed in the previous 9 months Within 24 hours following valve actuation due to automatic or manual action or flow through the valve (continued) Catawba Units 1 and 2 3.4.14-3 Amendment Nos. 28~&9

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.2.1 Verify the following valves are in the listed position with power to the valve operator removed. Number Position Function N1162A Open SI Cold Leg Injection Nl121A Closed SI Hot Leg Injection Nl152B Closed SI Hot Leg Injection N1183B Closed RHR Hot Leg Injection Nl173A Open RHRCold Leg Injection Nl178B Open RHR Cold Leg Injection Nl100B Open SI Pump Suction from RWST Nl147B Open SI Pump Mini-Flow SR 3.5.2.2

*----NOTE-*~--...:-**---------

Not required to be met for system vent flow paths opened under administrative control. Verify each ECCS manual, power operated, and automatic valve In the flow path, that ls not locked, sealed, or otherwise secured in position, is in the correct position. SR 3.5.2.3 Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water. ECCS - Operating 3.5.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Survei11ance Frequency Control Program SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required ~t": ~ developed head. ~1 TeslfAn ~i:enr-em (

"'--;:,-~

(continued) Catawba Units 1 and 2 3.5.2-2 Amendment Nos. ~BU178-

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.6.3.4 NOTE-------- Valves and blind flanges in high radiation areas may be verified by use of administrative means. Verify each containment isolation manual valve and blind flange that is located inside containment or annulus and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls. SR 3.6.3.5 Verify the isolation time of automatic power operated containment isolation valve is within limits. SR 3.6.3.6 Perform leakage rate testing for Containment Purge System, Hydrogen Purge System, and Containment Air Release and Addition System valves with resilient seals. SR 3.6.3.7 Verify each automatic containment isolation valve that is not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal. FREQUENCY Prior to entering MODE4from MODE 5 if not performed within the previous 92 days In accordance with the Containment Leakage Rate Testing Program In accordance with the Surveillance Frequency Control Program (continued) Catawba Units 1and2 3.6.3-6 Amendment Nos. -2691259

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.6.6.2 Verify each containment spray pump's developed head at the flow test point Is greater than or equal to the required developed head. SR 3.6.6.3 Deleted. SR 3.6.6.4 Deleted. SR 3.6.6.5 Verify that each spray pump is de-energized and prevented from starting upon receipt of a terminate signal and is allowed to manually start upon receipt of a start permissive from the Containment Pressure Controt System (CPCS). SR 3.6.6.6 Verify that each spray pump discharge valve closes or Is prevented from opening upon receipt of a terminate signal and is allowed to manually open upon receipt of a start permissive from the Containment Pressure Control System (CPCS}. SR 3.6.6.7 Verify each spray nozzle is unobstructed. SR 3.6.6.8 Verify containment spray locations susceptible to gas accumulation are sufficiently tilled with water. Catawba Units 1 and 2 3.6.6-2 FREQUENCY In accordance with the Surveillance Frequency Control Program 1n accordance with the Surveillance Frequency Control Program Following activities which could result in nozzle blockage ln accordance with the Survemance Frequency Control Program Amendment Nos. '182/278

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.1.1 NOTE Only required to be performed prior to entry into MODE2. Catawba Units 1 and 2 3.7.1-2 MSSVs 3.7.1 FREQUENCY Amendment Nos. -W9/185

ACTIONS (continued) CONDITION REQUIRED ACTION

0.

Required Action and D.1 Bein MODE 3. associated Completion nme of Condition C not AND met. D.2 Bein MODE4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.2.1 NOTE--- Only required to be performed prior to entry into MODE2. Verify closure time of each MSIV is within limits on an actual or simulated actuation signal. MS IVs 3.7.2 COMPLETION TIME 6 hours 12 hours FREQUENCY Catawba Units 1 and 2 3.7.2-2 Amendment Nos. ~238

MFIVs, MFCVs, Associated Bypass Valves and Tempering Valves 3.7.3 ACTIONS (continued} CONDITION REQUIRED ACTION

c.

One or more MFIV or C.1 Close or isolate bypass MFCV bypass valves valve. inoperable. ANQ C.2 Verify bypass valve is closed or isolated. I D. Two valves in the same D.1 Isolate affected flow path. flow path or the tempering valve inoperable. E. Required Action and E.1 Bein MODE3. associated Completion Time not met ~ E.2 Bein MODE4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.3.1 Verify the closure time of each MFIV, MFCV, their associated bypass valve, and the tempering valve is within limits on an actual or simulated actuation signal. COMPLETION TIME 72 hours Once per 7days 8 hours 6 hours 12 hours FREQUENCY Catawba Units 1and2 3.7.3-2 Amendment Nos. !441298

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.5.1 --NOTE----- Not applicable to automatic valves when THERMAL POWER is~ 10% RTP. Verify each AFW manual. power operated, and automatic valve in each water flow path, and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position. SR 3.7.5.2 NOTE:------ Not required to be performed for the turbine driven AFW pump until 24 hours after ?. 600 psig in the steam generator. Verify the developed head of each AFW pump at the flow test point is greater than or equal to the required developed head. SR 3.7.5.3 NOTE-------' Not applicable in MODE 4 when steam generator is relied upon for heat removal. Verify each AFW automatic valve that is not locked. sealed, or otherwise secured In position, actuates to the correct position on an actual or simulated actuation signal. AFWSystem 3.7.5 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Catawba Units 1 and 2 3.7.5-3 Amendment Nos. a&&Q5Q

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.8 lnserviO@ Testing Program~ This program provides controls or inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include e following:

a.

Testing frequencies applicable to the ASME Code for Oper ons and Maintenance of Nuclear Power Plants (ASME OM Code nd applicable Addenda as follows: ASME OM Code and applicable Addenda tenninology for inservice testi activities Weekly Monthly Quarterly or every 3 m Semiannually or eve Every 9 months Requir requencies for pert inginservicetesting vities 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

b.

The prov* ions of SR 3.0.2 are applicable to the above required Frequ cies and to other normal and accelerated Frequencies specified as 2 ears or less for performing inservice testing activities;

c.

e provisions of SR 3.0.3 are applicable to inservice testing activities; and Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS. 5.5.9 Steam Generator CSG) 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 (continued) Catawba Units 1 and 2 5.5-6 Amendment Nos. -289'218""

1.1 Definitions (continued) ENGINEERED SAFETY FEATURE(ESF)RESPONSE TIME LEAKAGE McGuire Units 1 and 2 Definitions 1.1 The ESF RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overtapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and the methodology for verification have been previously reviewed and approved by the NRC. LEAKAGE shall be:

a.

Identified LEAKAGE

1.

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

2.

LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or 3 Reactor Coolant System (RCS) LEAKAGE through a steam generator to the Secondary System (primary to secondary LEAKAGE);

b.

Unidentified LEAKAGE AH LEAKAGE (except RCP seal water injection or leakoff) that is not identified LEAKAGE;

c.

Pressure Boundarv LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall. 1.1-3 (continued) Amendment Nos. i37 f 219

SURVEILLANCE REQUIREMENTS SURVEILLANCE McGuire Units 1 and 2 3.4.10-2 Pressurizer Safety Valves 3.4.10 FREQUENCY Amendment Nos. t841 le6

SURVEILLANCE REQUIREMENTS SR 3.4.14.1 SURVEILLANCE

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

1.

Not required to be performed in MODES 3 and 4.

2.

Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3.

RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided. Verify leakage from each RCS PIV is equivalent to~ 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure.::, 2215 psig and ~ 2255 psig. RCS PIV Leakage 3.4.14 FREQUENCY Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months Within 24 hours following valve actuation due to automatic or manual action or flow through the valve (continued} McGuire Units 1 and 2 3.4.14-3 Amendment Nos. 261/i41

SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.5.2.4 Verify each ECCS pump's developed head at the test flow point Is greater than or equal to the required developed head. SR 3.5.2.5 Verify each ECCS automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. ECCS-Operating 3.5.2 FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.5.2.6 Verify each ECCS pump starts automatically on an actual In accordance with or simulated actuation signal. the Surveillance Frequency Conb'ol P ram SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, each position stop is in the correct position. Cenb'lfugal Charging Pump Injection Throttle Valve Number N1480 Nl481 Nl482 Nl483 Safety Injection Pump Throttle Valve Number Nl488 Nl489 Nl490 Nl491 In accordance with the Surveillance Frequency Control Program SR 3.5.2.8 Verify, by visual inspection, that the ECCS containment In accordance with sump strainer assembly and the associated enclosure are the Surveillance not restricted by debris and show no evidence of structural Frequency Control distress or abnonnal corrosion. Program McGuire Units 1 and 2 3.5.2-3 Amendment Nos. "281/241

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.6.3.4 NOTE.------- SR 3.6.3.5 SR 3.6.3.6 SR 3.6.3.7 Valves and blind flanges in high radiation areas may be verified by use of administrative controls. Verify each containment isolation manual valve and blind flange that is located inside containment or annulus and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls. Verify the isolation time of automatic power operated containment isolation valve is within limits. Perform leakage rate testing for containment purge lower and upper compartment and incore Instrument room valves with resilient seals. Verify each automatic containment isolation valve that is not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal. FREQUENCY Prior to entering MODE4from MODE 5 if not performed within the previous 92days In accordance with the Containment Leakage Rate Testing Program In accordance with the Surveillance Frequency control Program (continued) McGuire Units 1 and 2 3.6.3-6 Amendment Nos. !e 11241

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.2 Verify each containment spray pump's developed head at In accordance with the flow test point is greater than or equal to the required th developed head.

i:as~t-Prreararn-SR 3.6.6.3 Not Used Not Used SR 3.6.6.4 Not Used Not Used SR 3.6.6.5 Verify that each spray pump is de-energized and In accordance with prevented from starting upon receipt of a terminate signal the Surveillance and is allowed to manually start upon receipt of a start Frequency Control pennissive from the Containment Pressure Control Program S stem CPCS.

SR 3.6.6.6 Verify that each spray pump discharge valve closes or is prevented from opening upon receipt of a terminate signal and is allowed to manually open upon receipt of a start permissive from the Containment Pressure Control System (CPCS). SR 3.6.6. 7 Verify each spray nozzle is unobstructed. In accordance with the Surveillance Frequency Control Program Following activities which could result in nozzle blockage McGuire Units 1 and 2 3.6.6-2 Amendment Nos. 2721253

ACTIONS (continued) B. CONDITION REQUIRED ACTION Required Action and B.1 Be in MODE 3. associated Completion Time not met. AND One or more steam generators with less than two MSSVs OPERABLE. 8.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.1.1

NOTE-------

Only required to be performed prior to entry into MODE 2. MSSVs 3.7.1 COMPLETION TIME 6 hours 12 hours FREQUENCY McGuire Units 1 and 2 3.7.1-2 Amendment Nos. 4 8414 86

ACTIONS (continued) CONDITION REQUIRED ACTION D. Required Action and D.1 Bein MODE3. associated Comptetion Time of Condition C not AND met. 0.2 Bein MODE4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.2.1 NOTE-------- Only required to be performed prior to en~ into MODE 2. Verify closure time of each MSIV is s 8.0 seconds on an actual or simulated actuation signal. MSIVs 3.7.2 COMPLETION TIME 6 hours 12 hours FREQUENCY McGuire Units 1 and 2 3.7.2-2 Amendment Nos. 4 84'166

MFIVs, MFCVs, MFCV's Bypass Valves, and MFW/AFW NBVs 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION

c.

One or C.1 Close or isolate MFCV's more bypass valve or MFW/AFW MFCV's NBV. bypass valves or AND MFW/AFW NBVs C.2 Verify MFCV's bypass inoperable. valve or MFW/AFW NBV is closed or isolated. D. Two valves in the same 0.1 Isolate affected flow path. flow path inoperable. E. Required Action and E.1 Be in MODE 3. associated Completion Time not met. AND E.2 Bein MODE4. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3. 7.3.1 Verify the closure time of each MFIV, MFCV, MFCV's bypass valve, and MFW/AFW NBVis s 10 seconds on an actual or simulated actuation signal. COMPLETION TIME 72 hours Once per 7days 8 hours 6 hours 12 hours FREQUENCY McGuire Units 1 and 2 3.7.3-2 Amendment Nos. a.&1L188

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.5.1 NOTE------- Not applicable to automatic valves when THERMAL POWER is~ 10% RTP. Verify each AFW manual, power operated, and automatic valve In each water flow path, and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is In the correct position. SR 3.7.5.2 NOTE------ Not required to be performed for the turbine driven AFW pump until 24 hours after ~ 900 pslg In the steam generator. SR 3.7.5.3 NOTE------- Not applicable in MODE 4 when steam generator is relied upon for heat removal. Verify each AFW automatic valve that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signaf. AFWSystem 3.7.5 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program {continued) McGuire Units 1 and 2 3.7.5-3 Amendment Nos. 2811241

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.8 lnserviceTesting Proaram (bele+~) 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.

b.

c.

Testing frequencies applicable to the ASME Code for Operation a Maintenance of Nuclear Power Plants (ASME OM Code) and plicable Addenda as follows: ASME OM Code and applicable Addenda tennino\\ogy for inservice testin activities Weekly Monthly Semiannually or every 6 Every 9 months Yearly or annually Required Freque ies for performing ins

ce testing activities 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 The provisions R 3.0.2 are applicable to the above required CJ to other normal and accelerated Frequencies specified as 2 years less in the lnservice Testing Program for performing esting activities; T

provisions of SR 3.0.3 are applicable to inservice testing activities; nd Nothing in the ASME Boiler OM Code shall be construed to supersede the requirements of any TS. 5.5.9 Steam Generator (SGl 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. ~84:'289"

1.1 Definitions (continued) CONTROL RODS CORE ALTERATION CORE OPERATING LIMITS REPORT (COLR) DOSE EQUIVALENT 1-131 DOSE EQUIVALENT XE-133 tµ.SFWI~ i'FSTJrJG PIL06J!..A/VI OCONEE UNITS 1, 2, & 3 Definitions 1.1 CONTROL RODS shall be all full length safety and regulating rods that are used to shut down the reactor and control power level during maneuvering operations. CORE AL TERA TION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE AL TERA TIONS shall not preclude completion of movement of a component to a safe position. The COLR is the unit speciflC document that provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in indMdual Specifications. DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes 1-131, 1-132, 1-133, 1-134, and 1-135 actually present The determination of DOSE EQUIVALENT 1-131 shall be performed using Committed Dose Equivalent (COE) or Committed Effective Dose Equivalent (CEDE) dose conversion factors from Table 2.1 of the Environmental Protection Agency (EPA) Federal Guidance Report No. 11. DOSE EQUIV ALE NT XE-133 shall be that concentration of Xe-133 (microcuries per gram) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-85. Kr-87, Kr-88, Xe-131m, Xe-133m, Xe-133, Xe-135m, Xe-135, and Xe-138 actually present. If a specific noble gas nuclide is not detected, it should be assumed to be present at the minimum detectable activity. The determination of DOSE EQUIVALENT XE-133 shall be performed using effective dose conversion factors for air submersion listed in Table 111.1 of EPA Federal Guidance Report No. 12, 1993, "External Exposure to Radionucfldes in Air, Water, and Soil." -rtu_ I IV.St/LV 1c,e-l1;::SJIN(.,, p fi..06~M i.s ifA...... Ii ~s.e e-f '"',Y",..., -fk.. +- .fui -R //.1 -flu._ l't:.7.Jire 1AH'/I f3 o.f::- 10 Crfl-SO, 5.5 a.. ( -{:-), 1.1-3 Amendment Nos. 580, 982 & S81

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.10.1 OCONEE UNITS 1, 2, & 3 3.4.10-2 Pressurizer Safety Valves 3.4.10 FREQUENCY Amendment Nos. 389, 309, & aeg* I

HPI 3.5.2 SURVEILLANCE REQUIREMENTS (continued) SR 3.5.2.3 SR 3.5.2.4 SR 3.5.2.5 SR 3.5.2.6 SR 3.5.2.7 SURVEILLANCE FREQUENCY Verify each HPI pump's developed head at the In ~ ~ * ~* * ~*-with the test flow point is greater than or equal to the c* = . - "".'" __ ::. *~ :-. -.:1 -* **.) required developed head. fl Verify each HPI automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. Verify each HPI pump starts automatically on an actual or simulated actuation signal. Verify, by visual inspection, each HPI train reactor building sump suction inlet is not restricted by debris and suction inlet strainers show no evidence of structural distress or abnonnal corrosion. In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Cycle each HPI discharge crossover valve and In accordance with the LPl-HPI flow path discharge valve. J Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.5.2-5 Amendment Nos. 912, 314, 319

SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.5.3.2 Verify LPI locations susceptible to gas accumulation are sufficiently filled with water. SR 3.5.3.3 Verify each LPI pump's developed head at the required developed head. test flow point is greater than or equal to the ( SR 3.5.3.4 Verify each LPI automatic valve in the flow path that is not'locked, seated, or otherwise secured in position. actuates to the correct position on an actual or simulated actuation signal. SR 3.5.3.5 Verify each LPI pump starts automatically on an actual or simulated actuation signal. SR 3.5.3.6 Verify. by visual inspection, each LPI train reactor building sump suction inlet is not restricted by debris and suction Inlet strainers show no evidence of structural distress or abnormal corrosion. FREQUENCY LPI 3.5.3 In accordance with the Surveillance Frequency Control Program ln accordance with the =~~:rniD In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.5.3-3 Amendment Nos. 0981 499, ass

SURVEILLANCE REQUIREMENTS continued SR 3.6.3.4 SR 3.6.3.5 SURVEILLANCE Verify the isolation time of each automatic power operated containment isolation valve is within limits. Verify each automatic containment isolation valve that is not locked. sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal. Containment Isolation Valves 3.6.3 FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.6.3-5 Amendment Nos. 372, 37-4, 373

Reactor Building Spray and Cooling Systems 3.6.5 SURVEILLANCE REQUIREMENTS SR 3.6.5.1 SR 3.6.5.2 SR 3.6.5.3 SR 3.6.5.4 SURVEILLANCE ~~--~~~-NOTE~~*~----- Not required to be met for reactor building spray system vent flow paths opened under administrative control. Verify each reactor building spray and cooling manual and non-automatic power operated valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position. Operate each required reactor building cooling train fan unit for ~ 15 minutes. FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Verify each required reactor building spray In accordance with the pump's developed head at the flow test polnr*~: ____.: __ 7 __ ~- *q is greater than or equal to the required PPBSraM :tNS~l Vl.C.E;, developed head. "-.... TES.1'l:N G Ptt.o{,R_"H\\ Verify that the containment heat removal capability is sufficient to maintain post accident conditions within design limits. Jn accordance with the Surveillance Frequency Control Program (continued) OCONEE UNITS 1, 2, & 3 3.6.5-4 Amendment Nos. "998, 4 gg, 399"

3.7 PLANT SYSTEMS

3. 7.1 Main Steam Relief Valves (MSRVs)

MS RVs 3.7.1 LCO 3. 7.1 Eight MSRVs shall be OPERABLE on each main steam line. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION A. One or more MSRVs A.1 Bein MODE3. inoperable. AND A.2 Bein MODE4. SURVEILLANCE REQUIREMENTS SR 3.7.1.1 SURVEILLANCE

NOTE.~~--*

Only required to be performed in MODES 1 and2. Verify each MSRV lift set int in accordance with th tnser.;ee T-estiAg PFegram COMPLETION TIME 12 hours 18 hours FREQUENCY OCONEE UNITS 1, 2, & 3 3.7.1-1 Amendment Nos. 899, 300, & 399-

ACTIONS (continued) CONDITION REQUIRED ACTION C. Required Action and C.1 Be in MODE3. associated Completion Time not met. ~ C.2 Bein MOOE4. SURVEILLANCE REQUIREMENTS SR 3.7.3.1 SURVEILLANCE NOTE Only required to be performed in MODES 1 and2.

~-----------

Verify the closure time of each MFCV and SFCV is s 25 seconds on an actual or simulated actuation signal. MFCVs and SFCVs 3.7.3 COMPLETION TIME 12 hours 18 hours FREQUENCY In accordance with the lfteeNiee +e&tiRg PFegFaffi OCONEE UNITS 1, 2, & 3 3.7.3-2 Amendment Nos. 300, 300, & see

EFWSystem 3.7.5 SURVEILLANCE REQUIREMENTS SR 3.7.5.1 SR 3.7.5.2 SR 3.7.5.3 SR 3.7.5.4 SURVEILLANCE Verify each EFW manual, and non-automatic power operated valve in each water flow path and in the steam supply flow path to the turbine driven pump. that is not locked. sealed, or otherwise secured in position, is In the correct position. FREQUENCY In accordance with the Surveillance Frequency Control Program Verify the developed head of each EFW pump In accordance with the at the flow test point is greater than or equal I Jl:teeFViae l=eatiAI 1 to the required developed head. l !°'FelF&M J ~~------~NOTE~-~--~-- Not required to be met in MODES 3 and 4. Verify each EFW automatic valve that is not locked, sealed, or otherwise secured in position, actuates to the correct position on ar actual or simulated actuation signal.

~------NOTE------~----+

Not required to be met In MODES 3 and 4. Verify each EFW pump starts automatically on an actual or simulated actuation signal.

~

/ In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program SR 3. 7.5.5 Verify proper alignment of the required EFW Prior to entering MODE 2 flow paths by verifying valve alignment from whenever unit has been the upper surge tank to each steam l in MODE ~ or 6 for > 30 generator. days ~* OCONEE UNITS 1, 2, & 3 3.7.5-4 Amendment Nos. 672, 374, 373

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.10.1 Verify the required PSW battery terminal voltage is greater than or equal to the minimum established float voltage. SR 3.7.10.2 Verify the required Keowee Hydroelectric Station power supply can be aligned to and power the PSW electrical system. SR 3.7.10.3 Verify developed head of PSW primary and booster pumps at flow test point is greater than oy equal to the required developed head. SR 3.7.10.4 Verify PSW battery capacity of the required battery is adequate to supply, and maintain in OPERABLE status, required emergency loads for the design duty cycle when subjected to a battery service test. SR 3.7.10.5 Verify the required PSW battery charger supplies ~ 300 amps at greater than or equal to the minimum established float voltage for > ~ hours. OR Verify the required battery charger can recharge the battery to the fully charged state within 24 hours while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding PSW event discharge state. SR 3.7.10.6 NOTE Both HPI pump motors are individually tested although only one (1) HPI pump motor is required to support PSW system OPERABILITY. Verify that the required PSW switchgear and transfer switches can be aligned and power both the "A" and "B" HP\\ pump motors. SR 3.7.10.7 Perform functional test of required power transfer switches used for pressurizer heaters, PSW control, electrical panels, vital l&C chargers, and valves. PSWSystem 3.7.10 FREQUENCY In accordance with the Surveillance Frequency Control Program. In accordance with the Surveillance Frequency Control Program. _l,n accordance with the

~~ ~--*--

-) .;J=.. ;~~~'f~ In accordance with the Surveillance Frequency Control Program. In accordance with the Surveillance Frequency Control Program. In accordance with the Surveillance Frequency Control Program. In accordance with the Surveillance Frequency Control Program. (continued) OCONEE UNITS 1, 2, & 3 3.7.10-2 Amendment Nos. 388, 888, & 387

SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.7.10.8 NOTE Cooling water flow to the HPI pump motors are individually tested although only flow to the HPI pump motor aligned to PSW power is required to support PSW system OPERABILITY. Verify PSW booster pump and valves can provide adequate cooling water flow to HP' pump motor coolers. SR 3.7.10.9 Verify developed head of PSW portable pump at the flow test point is greater than or equal to required developed head. SR 3.7.10.10 Verify the required PSW valves are tested in accordance with th SR 3.7.10.11 Perform CHANNEL CHECK for each required PSW instrument channel. SR 3.7.10.12 Perform CHANNEL CALIBRATION for each required PSW instrument channel. SR 3.7.10.13 Verify for the required PSW battery that the cells, cell plates and racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance. PSWSystem 3.7.10 FREQUENCY In accordance with the In accordance with the Surveillance Frequency Control Program. In accordance with the Surveillance Frequency Control Program. In accordance with the Surveillance Frequency Control Program. In accordance with the Surveillance Frequency Control Program. OCONEE UNITS 1, 2, & 3 3.7.10-3 Amendment Nos. 386, 388, & 381 I

3. 7 Plant Systems SFPC Purification System Isolation from BWST 3.7.19 3.7.19 Spent Fuel Pool Cooling {SFPC) Purification System Isolation from Borated Water Storage Tank (BWST)

LCO 3. 7.19

a.

Two SFPC Purification System BWST automatic isolation valves shall be OPERABLE.

b.

SFPC Purification System branch line manual valves shall be closed and meet eakage requirements. t~ av, c.£ TcST'/!V6 P ft<<>t.A,A( APPLICABILITY: MODES 1, 2. 3 and 4 when the SFPC Purification System is not isolated from the BWST ACTIONS ~---------------------------NOTE~----------------------~-

1. SFPC Purification System flow path from the BWST may be unisolated intermittently under administrative controls.

2. Separate Condition entry allowed for each SFPC Purification System branch line manual valve.

CONDITION A. One automatic isolation A.1 valve inoperable. OCONEE UNITS 1, 2 1 & 3 AND A..2 REQUIRED ACTION COMPLETION TIME Isolate the flow path by 4 hours use of at least one closed and de-activated automatic valve, one closed and de-activated non-automatic power operated valve. closed manual valve, or blind flange. Verify the flow path is isolated. Once per 31 days (continued) 3.7.19-1 Amendment Nos. 385, 387, & 3&&

SFPC Purification System Isolation from BWST 3.7.19 SURVEILLANCE REQUIREMENTS SR 3.7.19.1 SR 3.7.19.2 SR 3.7.19.3 SR 3.7.19.4 SURVEILLANCE Verify SFPC Purification System branch line manual valves that are not locked, sealed, or otherwise secured in position are closed. Verify SFPC Purification System BWST automatic isola

BLE in accordance with the Verify each SFPC Purification System BWST automatic isolation valve that is not locked, sealed, or otherwise secured in position. actuates to the isolation position on an adual or simulated aduation signal.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.19-3 Amendment Nos..ass, 387, & 086

SURVEILLANCE REQUIREMENTS continued SR 3. 10.1.11 SR 3.10.1.12 SR 3.10.1.13 SURVEILLANCE Verify for required SSF battery that the cell to cell and terminal connections are clean, tight and coated with anti-corrosion material. Verify battery capacity of required battery is adequate to supply, and maintain in OPERABLE status, the required maximum loads for the design duty cycle when subjected to a battery service test. Perform CHANNEL CALIBRATION for each required SSF instrument channet. SR 3.10.1.15

NOTE-----*

Not applicable to the SSF submersible pump. FREQUENCY SSF 3.10.1 In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Verify the developed head of each required In accordance

h the SSF pump at the flow test point is greater JAseFYiee Te9tiAg than or equal to the required developed he dA. ~P..:..:re:.::g~F&=-"':.;.----

SR 3.10.1.16 Verify the developed head of the SSF submersible pump at the flow test point is greater than or equal to the required developed head. OCONEE UNITS 1, 2, & 3 3.10.1-5 In accordance with the Surveillance Frequency Control Program Amendment Nos. 972, 374, 37a

5.5 Programs and Manuals (continued) Programs and Manuals 5.5 5.5.7 Pre-Stressed Concrete Containment Tendon Surveillance Proaram This program provides controls for monitoring any tendon degradation in pre-stressed concrete containments, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. The program shall include baseline measurements prior to initial operations. The Tendon Surveillance Program, inspection frequencies, and acceptance criteria shall be in accordance with Section XI, Subsection IWL of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 1 O CFR 50.55a, as amended by relief granted in accordance with 10 CFR 50.55a(a)(3). The provisions of SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies. 5.5.8 Reactor Coolant Pump Flywheel Inspection Proaram This program shall provide for inspection of each reactor coolant pump flywheel. At approximately three-year intervals, the bore and keyway of each reactor coolant pump flywheel shall be subjected to an inplace, volumetric examination. Whenever maintenance or repair activities necessitate flywheel removal, a surface examination of exposed surfaces and a complete volumetric examination shall be performed if the interval measured from the previous such inspection is greater than 6 213 years. The interval may be extended up to one year to permit inspections to coincide with a planned outage. 5.5.9 lnservice Testina Proaram (D~I e~d i) This program provides controls for inservice testin and 3 pumps and valves:

a.

Testing frequencies ap Ii e ASME Code for Operations and Maintenan ear Power Plants (ASME OM Code) and applicable __,U\\.lllClnaa as follows: OCONEE UNITS 1, 2, & 3 5.0-12 Amendment Nos. aea. 995, a 994 I

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 lnservice Testing Proaram (continued) ASME OM 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 At I st once per 7 days 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

b.

The provisi s of SR 3.0.2 are applicable to the above required Frequen

s and to other normal and accelerated Frequencies specified as 2 rs or less in the lnservice Testing Program for performing
ce testing activities; 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. 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 uas 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.

OCONEE UNITS 1, 21 & 3 5.0-13 Amendment Nos. 996, 398, & 097 I

1.0 DEFINITIONS SECTION 1.1 ACTION.............. 1.2 ACTUATION LCXJIC TEST....... 1.3 ANALOG CHANNEL OPERATIONAL TEST. 1.4 AXIAL FLUX DIFFERENCE.. 1.5 CHANNEL CALIBRATION.. 1.6 CHANNEL CHECK..... 1.7 CONTAINMENT INTEGRITY.

1. 8 CONTROL LEO LEAKAGE..

1.9 CORE ALTERATION.... l.9a CORE OPERATING LIMITS REPORT 1.10 DIGITAL (}JANNEL OPERATIONAL TEST 1.11 DOSE EQUIVALENT I-131...... 1.12 E - AVERAGE DISINTEGRATION ENERGY. 1.13 ENGINEERED SAFETY FEATURES RESPONSE TIME 1.14 EXCLUSION AREA BOUNDARY...... 1.15 FREQUENCY NOTATION........ 1.16 GASEOUS RADWASTE TREATMENT SYSTEM. 1.17 IDENTIFIED LEAKAGE... 1.18 MASTER RELAY TEST......... 1.19 MEMBER(S) OF THE PUBLIC..... 1.20 OFFSITE DOSE CALCULATION MANUAL. 1.21 OPERABLE - OPERABILITY.. 1.22 OPERATIONAL tiJDE - MODE.. 1.23 PHYSICS TESTS....... 1.24 PRESSURE BOUNDARY LEAKAGE. 1.25 PROCESS CONTROL PROGRAM.. 1.26 PURGE - PURGING...... 1.27 QUADRANT POWER TILT RATIO.

1. 28 RATED THE~L POWER....

1.29 REACTOR TRIP SYSTEM RESPONSE TIME. 1.30 REPORTABLE EVENT..... 1.31 SH DOWN MARGIN...... PAGE 1-1 1-1 .... 1-1 1-1 .... 1-1 1-1 1-2 .... 1-2 1-2 1-2 I 1-2 .. l-2a I 1-3 1-3 .... 1-3 1-3 .... 1-3 1-3 1-4 1-4 1-4 1-4 1-4 1-4 ..... 1-4 1-5 1-5 1-5 1-5 I 1-5 1-5 1-5 \\, \\1c.v "l.NStRV1C,E:_ "TES\\I.N6 ~OGRJ\\ N\\ 1

I I

I I ' *** I

- - - \\-3 SHEARON HARRIS - UNIT 1 Amendment No. -iW.1-

DEFINITIONS E ~ AVERAGE DISINTEGRATION ENERGY 1.12 E shall be the average, weighted 1n proportion to the concentration of each radionuclide in the reactor coolant at the time of sampling. of the sum of the average beta and garnna energies per disintegration (MeV/d) for isotopes. with half-lives greater than 15 minutes. making up at least 95% of the total non*iodine activity in the coolant. ENGINEERED SAFETY FEATURES RESPONSE TIME 1.13 The ENGINEERED SAFETY FEATURES CESF) RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ESF Actuation Setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e.. the valves travel to their required positions. pump discharge pressures reach their required values. etc.). Times shall include diesel generator starting and sequence loading delays where applicable. The response time may be measured by means of any series of sequential. overlaRping. or total steps so that the entire response time is measured. In lieu of measurement. response time may be verified for selected components provided that the components and the methodology for ver1fication have been previously reviewed and approved by the NRC. EXCLUSION AREA BOUNDARY 1.14 The EXCLUSION AREA BOUNDARY shall be that line beyond which the land is not controlled by the licensee to limit access. FREQUENCY NOTATION 1.15 The FREQUENCY NOTATION specified for the performance of Surveillance Requirements shall correspond to the intervals defined in Table 1.1. GAS[OUS RAOWASTE TREATMENT SYSTEM 1.16 A GASEOUS RADWASTE TREATMENT SYSTEM is any system designed and installed to reduce radioactive gaseous effluents by collecting pr1mary coolant system off-gases from the primary system and providing for aelay or holdup for the purpose of reducing the total radioact1v1ty pr1or to release to the environment. IDENTIFIED LEAKAGE 1.17 IDENTIFIED LEAKAGE shall be:

a.

Leakage <except CONTROLLED LEAKAGE> into closed systems. such as pump seal or valve packing leaks that are capturea and conducted to a sump or collecting tank. or

b.

Leakage 1nto the containment atmosphere from sources that are both specifically located and known elther not to interfere with the operation of Leakage Detection Systems or not to be PRESSURE BOUNDARY LEAKAGE. or

c.

Reactor Coolant System leakage through a steam generator to the Secondary Coolant System (pr1mary-to-secondary leakage). QmE~T HNP \\.~'.20 SHEARON HARRIS - UNIT 1 1-3 Amendment No. ~

INSERT HNP 1.17a INSERVICE TESTING PROGRAM 1.17a The INSERVICE TESTING PROGRAM is the licensee program that fulfills the requirements of 10 CFR 50.55a(f).

REACTIVITY CONTROL SYSTEMS CHARGING PUMP - SHUTDOWN LIMITING CONDITION FOR OPERATION 3.1.2.3 One charging/safety injection pump in the boron 1njection flow path required by Specification 3.1.2.l shall be OPERABLE and capable of being powered from an OPERABLE emergency power source. APPLICA81LIJY: t4JOES 4*. 5*1

and 6*1.

ACTION: With no charging/safety inJection pump OPERABLE or capable of being powered fran an OPERABLE emergency power source. suspend all operations involving CORE ALTERATIONS or positive reactivity changes. SURVEILLANCE REQUIREMENTS 4.1.2.3.l The above required charging/safety injection pump shall be demonstrated OPERABLE by verifying. on recirculat10n flow or in service supply1ng flow to the reactor coolant system and reactor coolant PllnP seals. that a differential pressure across the pump of gre_~tei:ir~t~h~ae:n:loiir~e~uncaat=:ptl;eoifiiiiii. 2446 psid is developed when tested pursuant to the1~ --~----~--~--~ 4.1.2.3.2 All charging/safety injection pumps, excluding the above requ1reCI OPERABLE punp, shall be demonstrated inoperable~* by verifying that each pump*s motor circuit breaker is secured 1n the open position pr1or to the temperature of one or more of the RCS cold legs decreasing below 325°F and at least once per 31 days thereafter, except when the reactor vessel head 1s removed.

A maximum of one charging/safety 1nJect1on Pl.111P shall be OPERABLE whenever the temperature of one or more of the RCS cold legs is less than or equal to 325°F and the reactor vessel head is in place.

An inoperable pump may be energized for testing provided the discharge of the p~ has been lsolated fran the RCS by a closed isolat1on valve with power renK>Ved from the valve operator or by a manual isolat1on valve secured in the closed pos1tion. ' For peri ads of no more than 1 hour. when swapping pumps. it 1 s penni tted that there be no OPERABLE charging/safety injection pump. No CORE ALTERATIONS or positive reactivity changes are pen1ntted during this time. SHEARON HARRIS - UNIT l 3/4 1-9 Amendment No -tfT-

~~~-------------------------------------------------------------------~ REACTIVITY CONTROL SYSTEMS CHARGING PUMPS - OPERATING LIMITING CONDITION FOR OPERATION 3.1.2.4 At least two charging/safety injection pumps shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTION: With only one charging/safety injection pump OPERABLE, restore at least two charging/safety injection pumps to OPERABLE status within 72 hours* or be in at least HOT STANDBY and borated to a SHUTDOWN MARGIN as specified in the CORE OPERA TING LIMITS REPORT (COLR), plant procedure PLP-106 at 200°F within the next 6 hours; restore at least two charging/safety injection pumps to OPERABLE status within the next 7 days or be in HOT SHUTDOWN within the next 6 hours. NOTE-------------------------~--

The 'A' Train charging/safety pump is allowed to be inoperable for a total of 14 days only to allow for the implementation of design improvements on the 'A' Train ESW pump. The 14 days will be taken one time no later than October 29, 2016. During the period in which the 'A' Train ESW pump supply from the Auxiliary Reservoir or Main Reservoir is not available, Normal Service Weter will remain available and in service to supply the 'A' Train ESW equipment loads until the system is ready for post maintenance testing. Allowance of the extended Completion Time is contingent on meeting the Compensatory Measures and Conditions described in the HNP LAR submittal correspondence letter HNP-16-056.

SURVEILLANCE REQUIREMENTS 4.1.2.4 At least two charging/safety injection pumps shall be demonstrated OPERABLE by verifying, on recirculation flow or in service supplying flow to the Reactor Coolant System and reactor coolant pump seals, that a differential pressure across each pump of greater than or ual to 2446 psid is developed when tested pursuant to the SHEARON HARRIS - UNIT 1 3/4 1-10 Amendment No. 463-

REACTOR COOLANT SYSTEM 3/4.4.2 SAFETY VALVES SHUTDOWN LIMITING CONDITION FOR OPERATION 3.4.2.1 A minimum of one pressurizer Code safety valve shall be OPERABLE w1th a 11ft sett1ng of 2485 psig +/- it: APPLICABILITY: MODES 4 and 5 ACTION: W1th no pressur1zer Code safety valve OPERABLE. 1111ned1ately suspend all operations involving positive react1vity changes and place an OPERABLE RHR loop into operation 1n the shutdown cooling mode. SURVEILLANCE REQUIREMENTS

rhe lift setting pressure shall correspond to ambient cond1tions of the valve at nomi na 1 opera tf ng tempera tu re and pressure SHEARON HARR f S
UN IT 1 314 4-B Amendment No ~

REACTOR COOLANT SYSTEM QPERATING LIMITING CONDITION FOR OPERATION 3.4.2.2 All pressurizer Code safety valves shall be OPERABLE with a lift setting of 2485 psig +/- ii: APPLICABILITY: P()()E5 1. 2. and 3. ACTION: With one pressurizer Code safety valve inoperable, either restore the inoperable valve to OPERABLE status within 15 m1nutes or be in at least HOT STANDBY Within 6 hours and in at least HOT SHLJT()(MN within the following 6 hours. SURVEILLANCE REQUIREMENTS

The lift setting pressure shall correspond to ambient condit1ons of the valve at naninal operating temperature and -pressure.

SHEARON HARRIS

UNIT 1 3/4 4-9 Amendment No ~

REACTOR COOLANT SYSTEM RELIEF VALVES SURVEILLANCE REQUIREMENTS 4.4.4.1 In addition to the requirements of the~itffteP.Hee~etif'6-J~~~ each PORV shall be demonstrated OPERABLE at the frequency spec urveillance Frequency Control Program by:

a.

Performing a CHANNEL CALIBRATION of the actuation instrumentation, and

b.

Operating the valve through one complete cycle of full travel during MODES 3 or 4, prior to going to 325°F. 4.4.4.2 Each block valve shall be demonstrated OPERABLE at the frequency specified in the Surveillance Frequency Control Program by operating the valve through one complete cycle of full travel unless the block valve is closed with power removed in order to meet the requirements of ACTION b. or c. in Specification 3.4.4. 4.4.4.3 The accumulator for the safety-related PORVs shall be demonstrated OPERABLE at the frequency specified in the Surveillance Frequency Control Program by isolating the normal air and nitrogen supplies and operating the valves through a complete cycle of full travel. SHEARON HARRIS - UNIT 1 3/4 4-12 Amendment No. 4i4-

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

d.

At the frequency specified in the Surveillance Frequency Control Program by:

1.

Verifying automatic interlock action of the RHR system from the Reactor Coolant System by ensuring that with a simulated or actual Reador Coolant System pressure signal greater than or equal to 425 psig the interlocks prevent the valves from being opened.

2.

A visual inspection of the containment sump and verifying that the subsystem suction inlets are not restricted by debris and that the sump components (trash racks, screens, etc.) show no evidence of structural distress or abnormal corrosion.

e.

At the frequency specified in the Surveillance Frequency Control Program by:

1.

Verifying that each automatic valve in the flow path actuates to its correct position on safety injection actuation test signal and on safety injection switchover to containment sump from an RWST Lo-Lo level test signal, and

2.

Verifying that each of the following pumps start automatically upon receipt of a safety injection actuation test signal: a) Charging/safety injection pump, b) RHR pump.

f.

By verifying that each of the following um s develops the required differential pressure when tested pursuant to thel1M~~* ~-Rna~QQiaftl

1.

Charging/safety injection pump (Refer to Specification 4.1.2.4)

2.

RHR pump t! 100 psid at a flow rate of at least 3663 gpm.

g.

By verifying that the locking mechanism is in place and locked for the following High Head ECCS throttle valves:

1.

Within 4 hours following completion of each valve stroking operation or maintenance on the valve when the ECCS subsystems are required to be OPERABLE! and

2.

At the frequency specified in the Surveillance Frequency Control Program. SHEARON HARRIS - UNIT 1 3/4 5-5 Amendment No. ~

CONTAINMENT SYSTEMS 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS CONTAINMENT SPRAY SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.1 Two independent Containment Spray Systems shall be OPERABLE with each Spray System capable of taking suction from the RWST and transferring suction to the containment sump. APPLICABILITY: MODES 1, 2, 3, and 4. ACTION: With one Containment Spray System inoperable, restore the inoperable Spray System to OPERABLE status within 72 hours** or be in at least HOT STANDBY within the next 6 hours; restore the inoperable Spray System to OPERABLE status within the next 48 hours or be in COLD SHUTDOWN within the following 30 hours. Refer also to Specification 3.6.2.3 Action. ~----------~--~--~----~~NOTE~------~--------~--~-----

- The 'A' Train Containment Spray System is allowed to be inoperable for a total of 14 days only to allow for the implementation of design improvements on the 'A' Train ESW pump. The 14 days will be taken one time no later than October 29, 2016. During the period in which the 'A' Train ESW pump supply from the Auxinary Reservoir or Main Reservoir is not available, Normal Service Water will remain available and in service to supply the 'A' Train ESW equipment loads until the system is ready for post maintenance testing. Allowance of the extended Completion Time is contingent on meeting the Compensatory Measures and Conditions described in HNP LAR submittal correspondence letter HNP-16-056.

SURVEILLANCE REQUIREMENTS 4.6.2.1 Each Containment Spray System shall be dem~nstrated OPERABLE:

a.

At the frequency specified in the Surveillance Frequency Control Program by verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position*;

b.

By verifying that. on an indicated recirculation flow of at least 1832 gpm, each um de

di erential pressure of greater than or equal to 186 psi when tested pursuant tot

c.

At the frequency specified in the Surveillance Frequency Control Program by:

1.

Verifying that each automatic valve in the flow path actuates to its correct position on a containment spray actuation test signal and

2.

Verifying that each spray pump starts automatically on a containment spray actuation test signal.

3.

Verifying that, coincident with an indication of containment spray pump running, each automatic valve from the sump and RWST actuates to its appropriate position following an RWST Lo-Lo test signal.

d.

At the frequency specified in the Surveillance Frequency Control Program by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

e.

At the frequency specified in the Surveillance Frequency Control Program by verifying that containment spray locations susceptible to gas accumulation are sufficiently filled with water. Not required to be met for system vent flow paths opened under administrative control. SHEARON HARRIS - UNIT 1 3/4 6-11 Amendment No.~

CONTAINMENT SYSTEMS CONTAINMENT ISOLATION VALVES SURVEILLANCE REQUIREMENTS (Continued) 4.6.3.2 Each isolation valve shall be demonstrated OPERABLE at the frequency specified in the Surveillance Frequency Control Program by:

a.

Verifying that on a Phase "A" Isolation test signal, each Phase "A" isolation valve actuates to its isolation position;

b.

Verifying that on a Phase "B" Isolation test signal, each Phase "B" isolation valve actuates to its isolation position; and

c.

Verifying that on a Containment Ventilation Isolation test signal, each normal, preentry purge makeup and exhaust, and containment vacuum relief valve actuates to its isolation position, and

d.

Verifying that, on a Safety Injection "S" test signal, each containment isolation valve receiving an "S" signal actuates to its isolation position, and

e.

Verifying that, on a Main Steam Isolation test signal, each main steam isolation valve actuates to its isolation position, and

f.

Verifying that, on a Main Feedwater Isolation test signal, each feedwater isolation valve actuates to its isolation position. 4.6.3.3 The isolation time of each power-operated or automatic valve shall be determined to be within its limit specified in the Technical Specification E ui ment List Program, plant procedure PLP-106, when tested pursuant to the@~~*~~~~~~ SHEARON HARRIS - UNIT 1 3/4 6-15 Amendment No. -454-

CONTAINMENT SYSTEMS 3/4.6.5 VACUUM RELIEF SYSTEM LIMITING CONDITION FOR OPERATION 3.6.S The containment vacuum relief system shall be OPERABLE with an Actuation Setpo1nt of equal to or less negative than -2.5 1nches water gauge differential pressure Ccontairrnent pressure less atmospher1c pressure> APPLICA81LIIV: t{)OES 1. 2. 3. and 4. ACTION: With one conta1nrnent vacuum relief system inoperable. restore the system to OPERABLE status within 72 hours or be m at least HOT STANDBY w1thin the next 6 hours and in COLD SHlfll)(}JN within the following 30 hours SURVEILLANCE REQUIREMENTS SHEARON HARRIS

UNIT 1 3/4 6-32 Amendment No. -TZ7-

314.7 PLANT SYSTEMS 3/4.7.1 TURBINE CYCLE SAFITT VALVES LIMITING CONDITION FOR OPERATION 3.7.l.l All main steam l1ne Code safety valves associated with each steam generator shall be OPERABLE with lift settings as specified in Table 3.7-2. APPLICA8ILITY: K>OES 1. 2. and 3. ACTIQN:

a.

With one or more ma1n steam* l1ne Code safety valves inoperable. operation may proceed provided. that within 4 hours. either the inoperable valve is restored to OPERABLE status or the Power Range Neutron Flux High Tr1p Setpoint is reduced per Table 3.7-1: otherwise. be in at least HOT STANDBY within the next 6 hours and in HOT SHUTIXMN within the following 6 hours. SURVEILLANCE REQUIREMENTS SHEARON HARRIS - UNIT 1 3/4 7-1 Amendment No. ~

PLANT SYSTEMS MAIN SIEAH LINE ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.7.1.5 Each ma1n steam line isolation valve (MSIV) shall be OPERABLE AePLICA81LITY: t-l>DES 1. 2. 3. and 4. ACTION: t()OE 1: With one MSIV inoperable but open. POWER OPERATION may continue provided the inoperable valve is restored to OPERABLE status within 4 hours: otherw1 se be in HOT STANDBY w1 thin the next 6 hours and 1 n HOT SHlffDCMN within the following 6 hours. r<>DES 2. 3. and 4: With one MSIV inoperable. subsequent operat1on in K>DE 2. 3. or 4 may proceed provided the isolation valve is maintained closed. Otherwise. be 1n HOT STANDBY within the next 6 hours and 1n HOT SHUTDOWN w1thin the following 6 hours. SURVEILLANCE REQUIREMENTS SHEARON HARRIS UNIT 1 3/4 7-9 Amencinent No. ~

PLANT SYSTEMS 314.7.13 ESSENTIAL SERVICES CHILLED WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.13 At least two independent Essential Services Chilled Water System loops shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTION: \\Nith only one Essential Services Chilled Water System loop OPERABLE, restore at least two loops to OPERABLE status within 72 hours* or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. --~~-NOTE~~~~~-

The 'A' Train Essential Services Chilled Water System loop is allowed to be inoperable for a total of 14 days only to allow for the implementation of design improvements on the 'A' Train ESW pump. The 14 days will be taken one time no later than Odober 29, 2016. During the period in which the 'A' Train ESW pump supply from the Auxiliary Reservoir or Main Reservoir is not available. Normal Service Water will remain available and in service to supply the 'A' Train ESW equipment loads until the system is ready for post maintenance testing. Allowance of the extended Completion Time is contingent on meeting the Compensatory Measures and Conditions described in HNP LAR submittal correspondence letter HNP-16-056.

SURVEILLANCE REQUIREMENTS 4.7.13 The Essential Services Chilled Water System.shall be demonstrated OPERABLE by:

a.

Performance of surveillances as required by the and

b.

At the frequency specified in the Surveillance Frequency Control Program by demonstrating that:

1.

Non-essential portions of the system are automatically isolated upon receipt of a Safety Injection actuation signal, and

2.

The system starts automatically on a Safety Injection actuation signal. SHEARON HARRIS - UNIT 1 3/4 7-30 Amendment No. -464-

AOM!NlSfRATIVE CONTROLS PROCCOURfS A.NO PROGRAMS c Cgr1t 1 nued) rr .l.fil.erv1ce lest mo Program ((De 1~.l.c d )) his prog!*"t1rn prov1des contrc?s for rns~rv1ce test 1ng of.l\\SME. .. lass l. 2. and 3 components ThP progrrim shall include th~ fo 11 OWi ng U Test mg f reQuenu es soec if 1 ed rn thP ASME Code for OQ _rat ion and Maintenance of Nuclear Power Plants an1j appl 1rable denda a.s fo 11ows

ASME Code for Ope,.. at 1 on and Ma Mtenance of Nuc It-a r Power P 1 ants and apµ 11cab1 e Addenda terminology for lnserv1ce testing act1v1t1es Weekly Monthly Oudrterly or* every 3 rnonths Semi armua 1 *1 y or every 6 mont h':i Every 9 months

'(early or dnnua 1 ly B1enn1~lly or every 2 years for test1ng least once per 7 days L~as t once per 31 days lea~t once pff 92 days least once per 184 days least once per 276 days least once per 366 dayC) least once per 731 ddys ?) T_he prov1.$1on~ of S' 1~ 0 i' are appl1cdble to th~ above requ1red FrP.quenc: 1 es and t - oth1:;,r normal and arTe 1 era ted F requeflc I es spec1hed dS 2 dr~. or lesi; in t.he Inserv1ce Testing ProgrQm for perfor*m1nr rn;;enice t~sting Jct.1vities.

3) r he pf o*-1 i

on~ of SH 4 O 3 are app 11*:ctb1 e to insenn ce te-;t 1 nq aclivit*.. s. and l>

Notb ng l11 the ASMf Code for Operation and Marnteodnce of

ear Power Plants shall be construed t.o supersede tr1e t'eqtJirements of any Techmcal Specificat.lon I

1 **11 1

1.1 Definitions ~-AVERAGE DISINTEGRATION ENERGY (continued) LEAKAGE MASTER RELAY TEST MODE HBRSEP Unit No. 2 iodines, with half lives > 15 minutes, making up at least 95% of the total noniodine activity in the coolant LEAKAGE shall be;

a.

Identified LEAKAGE Definitions 1.1

1.

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

2.

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

3.

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

b.

Unidentified LEAKAGE All LEAKAGE (except RCP seal water injection or return) that is not identified LEAKAGE;

c.

Pressure Boundarv LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall. A MASTER RELAY TEST shall consist of energizing each master relay and verifying the OPERABILITY of each relay. The MASTER RELAY TEST shall include a continuity check of each associated slave relay. A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning (continued) 1.1-3 Amendment No. "143-

SURVELLANCE REQUIREMENTS SURVELLANCE SR 3.4.10.1 HBRSEP Unit No. 2 3.4-24 Pressurizer Safety Valves 3.4.10 FREQUENCY Amendment No. ~

SURVEILLANCE REQUIREMENTS SR 3.4.14.1 SURVEILLANCE NOTES-

1.

Not required to be performed in MODES 3 and 4.

2.

Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3.

RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided. RCS PIVs 3.4.14 FREQUENCY Verify leakage from each RCS PIV is less than or In accordance with equal to an equivalent of 5 gpm at an RCS pressure ir? 2235 psig, and verify the margin between the results of the previous leak rate test and the 5 gpm limit has not been reduced by 2: 50% for valves with leakage rates > 1. 0 gpm. Ar::!Q HBRSEP Unit No. 2 3.4-39 Prior to entering MODE2 whenever the unit has been in MODE 5for 7 days or more, if leakage testing has not been performed in the previous 9 months (continued) Amendment No. -+Te-

ECCS.. Operating 3.5.2 SUREILLANCE REQUIREMENTS continued SR 3.5.2.3 SR 3.5.2.4 SR 3.5.2.5 SR 3.5.2.6 SURVEILLANCE FREQUENCY Verify each ECCS pump's developed head at the test In a~rdance with flow point is greater than or equal to the required developed head. Verify each ECCS automatic valve in the flow path 18 months that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. Verify each ECCS pump starts automatically on an 18 months actual or simulated actuation signal. Verify, by visual inspection, the ECCS train 18 months containment sump suction inlet is not restricted by debris and the suction inlet trash strainers show no evidence of structural distress or abnormal corrosion. (continued) HBRSEP Unit No. 2 3.5-6 Amendment No.~

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS continued SR 3.6.3.4 SR 3.6.3.5 SR 3.6.3.6 SURVEILLANCE Verify the isolation time of each automatic power operated containment isolation valve is within limits. FREQUENCY Verify each automatic containment isolation valve 18 months that is not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal. Verify each 42 inch inboard containment purge valve 18 months is blocked to restrict the valve from opening > 700. HBRSEP Unit No. 2 3.6-12 Amendment No.~

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.6.2 SR 3.6.6.3 SR 3.6.6.4 SR 3.6.6.5 SR 3.6.6.6 SR 3.6.6.7 SR 3.6.6.8 SURVEILLANCE Operate each containment cooling train fan unit for i? 15 minutes. Verify cooling water flow rate to each cooling unit is i?! 750 gpm. FREQUENCY 31 days 31 days Verify each containment spray pump*s developed In accordance with head at the flow test point is greater than or equal to the*--*.. : __ ' the required developed head. _( Testi~ Pregram) (r \\ Verify each automatic containment spray valve in the 18 months flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. Verify each containment spray pump starts automatically on an actual or simulated actuation signal. Verify each containment cooling train starts automatically on an actual or simulated actuation signal. Verify each spray nozzle is unobstructed. 18 months 18 months Following activities which could result In nozzle blockage HBRSEP Unit No. 2 3.6-17 Amendment No. 118 194

Isolation Valve Seal Water System 3.6.8 SURVEILLANCE REQUIREMENTS continued SR 3.6.8.3 SR 3.6.8.4 SR 3.6.8.5 SR 3.6.8.6 HBRSEP Unit No. 2 SURVEILLANCE Verify the opening time of each air operated header injection valve is within limits. Verify each automatic valve in the IVSW System actuates to the correct position on an actual or simulated actuation signal. Verify the IVSW dedicated nitrogen bottles will pressurize the IVSW tank to 2: 46.2 psig. Verify total IVSW seal header flow rate is s 124 cc/minute 3.6-21 FREQUENCY 18 months 18 months 18 months Amendment No.~

SURVEILLANCE REQUIREMENTS SR 3.7.1.1 SURVEILLANCE

NOTE~~~~~~~

Only required to be performed in MODES 1 and 2. HBRSEP Unit No. 2 3.7-3 MSSVs 3.7.1 FREQUENCY Amendment No.~

ACTIONS (continued) CONDITION REQUIRED ACTION D. Required Action and associated Completion Time of Condition C not met. D.1 Be in MODE 3. AND 0.2 Be in MODE 4. SURVEILLANCE REQUIREMENTS URVEILLANCE SR 3.7.2.1 HBRSEP Unit No. 2

NOTE-Only required to be performed in MODES 1 and2.

Verify closure time of each MSIV is within limits on an actual or simulated actuation signal. 3.7-7 MS IVs 3.7.2 COMPLETION TIME 6 hours 12 hours FRE ENCY In accordance with the Amendment No...ZS7

MFIVs, MFRVs. and Bypass Valves 3.7.3 ACTIONS <continued) CONDITION REQUIRED ACTION C. One or more bypass C.1 Close or isolate bypass valves inoperable. valve. AND C.2 Verify bypass valve is closed or isolated.

0. Two valves in the 0.1 Isolate affected flow same flow path path.

inoperable. E. Required Action and E.1 Bein MODE3. associated Completion Time not met. AND E.2 Be in MODE 4. SURVEILLANCE RE UIREMENTS SURVEILLANCE SR 3. 7.3.1 Verify the closure time of each MFRV and bypass valve is within limits on an actual or simulated actuation signal. SR 3. 7.3.2 Verify the closure time of each MFIV is within limits on an actual or simulated actuation signal. HBRSEP Unit No. 2 3.7-9 COMPLETION TIME 8 hours Once per 7 days 8 hours 6 hours 12 hours IR&eP\\*iee Ta&tiRg Pregrem Amendment No.~

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5. 7 Reactor Coolant Pump Flvwheel lnsoection Proa ram HBRSEP This program provides controls for the inspection of each reactor coolant pump flywheel in accordance with the lnservice Inspection Program. lnservice Testing Proaram~e/ :~c!"}) This program provides controls for inservice testing of ASME Code Class and 3 pumps and valves. The program shall include the following:

a.

Testing frequencies specified in Section XI of the ASME B Pressure Vessel Code and applicable Addenda as follo 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 everv. 2 years Frequencies rming inservice ctivities 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

b.

The provi

ns of SR 3.0.2 are applicable to the above required Freque 1es for performing inservice testing activities;

c.

i: provisions of SR 3.0.3 are applicable to inservice testing activities; and Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any TS. No.Le.: $-cc..S~c.~10¥\\- Li J;,,. ../~ ~f;A;l-1~ o.+ iAJS~~VIC~ Tt...S71Nl> f.R..~Aµ,, ------ 5.0-11 (continued) Amendment No...ue-to RA-17-0005 Proposed Technical Specification Bases Changes (Mark-up) (For Information Only)

SR Applicability B 3.0 B 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY BASES SRs SR 3.0.1 through SR 3.0.5 establish the general requirements applicable to all Specifications and apply at all times, unless otherwise stated.._ ___ _ SR 3.0.1 SR 3.0.1 establishes the requirement that SRs must be met during the MODES or other specified conditions in the Applicability for which the requirements of the LCO apply, unless otherwise specified in the individual SRs. This Specification is to ensure that Surveillances are performed to verify the OPERABILITY of systems and components, and that variables are within specified limits. Failure to meet a Surveillance within the specified Frequency, in accordance with SR 3.0.2, constitutes a failure to meet an LCO. Systems and components are assumed to be OPERABLE when the associated SRs have been met. Nothing in this Specification, however, is to be construed as implying that systems or components are OPERABLE when:

a.

The systems or componen~s are known to be inoperable, although still meeting the SRs; or

b.

The requirements of the SutveiHance(s) are known not to be met between required Surveillance performances. Surveillances do not have to be performed when the unit is in a MODE or other specified condition for which the requirements of the associated LCO are not applicable, unless otherwise specified. The SRs associated with a test exception are only applicable when the test exception is used as an allowable exception to the requirements of a Specification. Unplanned events may satisfy the requirements (including applicable acceptance criteria) for a given SR. In this case, the unplanned event may be credited as fulfilling the performance of the SR. This allowance includes those SRs whose performance is normally precluded in a given MODE or other specified condition. Surveillances, including Surveillances invoked by Required Actions, do not have to be performed on inoperable equipment because the ACTIONS define the remedial measures that apply. Surveillances have to be met and performed in accordance with SR 3.0.2, prior to returning equipment to OPERABLE status. Catawba Units 1and2 8 3.0-14 Revision No.....a-

BASES SR 3.0.1 (continued) SR 3.0.2 SR Applicability B 3.0 Upon completion of maintenance, appropriate post maintenance testing is required to declare equipment OPERABLE. This includes ensuring applicable Surveillances are not failed and their most recent performance is in accordance with SR 3.0.2. Post maintenance testing may not be possible in the current MODE or other specified conditions in the Applicability due to the necessary unit parameters not having been established. In these situations, the equipment may be considered OPERABLE provided testing has been satisfactorily completed to the extent possible and the equipment is not otherwise believed to be incapable of performing its function. This will allow operation to proceed to a MODE or other specified condition where other necessary post maintenance tests can be completed. SR 3.0.2 establishes the requirements for meeting the specified Frequency for Surveillances and any Required Action with a Completion Time that requires the periodic performance of the Required Action on a "once per... " interval. SR 3.0.2 permits a 25% extension of the interval specified in the Frequency. This extension facilitates Surveillance scheduling and considers plant operating conditions that may not be suitable for conducting the Surveillance (e.g., *transient conditions or other ongoing Surveillance or maintenance activities). Catawba Units 1 and 2 B 3.0-15 Revision No. 4-

INSERT 1 CNS Bases SR 3.0.2 When a Section 5.5, "Programs and Manuals," specification states that the provisions of SR 3.0.2 are applicable, a 25% extension of the testing interval, whether stated in the specification or incorporated by reference, is permitted. INSERT 2 CNS Bases SR 3.0.2 The exceptions to SR 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply. These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS. Examples of where SR 3.0.2 does not apply are the Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the inservice testing of pumps and valves in accordance with applicable American Society of Mechanical Engineers Operation and Maintenance Code, as required by 10 CFR 50.55a. These programs establish testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot, in and of themselves, extend a *test interval specified in the regulations directly or by reference.

BASES SR 3.0.2 (continued) SR 3.0.3 SR Applicability B 3.0 As stated in SR 3.0.2, the 25% extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a "once per... " basis. The 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a sihgle action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or the action accomplishes the function of the inoperable equipment in an altemative manner. The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified. SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours or. up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the Survemance has not been perfonned in accordance with SR 3.0.2, and not at the time that the specified Frequency was not met. This delay period provides adequate time to complete Surveillances that have been missed. This delay period permits the completion of a Surveillance before complying with Required Actions or other remedial measures that might preclude completion of the Surveillance. The basis for this delay period includes consideration of unit conditions, adequate planning, availability of personnel, the time required to perform the Surveillance, the safety significance of the delay in completing the required Surveillance, and the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the requirements. Catawba Units 1 and 2 B 3.0-16 Revision No...+-

INSERT CNS Bases SR 3.0.3 When a Section 5.5, *programs and Manuals," specification states that the provisions of SR 3.0.3 are applicable, it permits the flexibility to defer declaring the testing requirement not met in accordance with SR 3.0.3 when the testing has not been completed within the testing interval (including the allowance of SR 3.0.2 if invoked by the Section 5.5 specification).

BASES Pressurizer Safety Valves B 3.4.10 ACTIONS (continued) B.1 and B.2 If the Required Action of A.1 cannot be met within the required Completion Time or if two or more pressurizer safety valves are inoperable, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 4 with any RCS cold leg temperatures~ 210°F within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. With any RCS cold leg temperatures at or below 210°F I overpressure protection is provided by the L TOP System. The change from MODE 1, 2, or 3 to MODE 4 reduces the RCS energy (core power and pressure), lowers the potential for large pressurizer insurges, and thereby removes the need for overpressure protection by three pressurizer safety valves. SURVEILLANCE SR 3.4.10. 1 REQUIREMENTS REFERENCES SRs are specified in the . Pressurizer safety valves are to be tested in accor ance w1 e requirements of Section XI of the ASME Code (Ref. 4), which provides the activities and Frequencies necessary to satisfy the SRs. No additional requirements are specified. The pressurizer safety valve setpoint is +3% and -2% of the nominal setpoint of 2485 psig for OPERABILITY; however, the valves are reset to +/- 1 % during the Surveillance to allow for drift.

1.

ASME, Boiler and Pressure Vessel Code, Section Ill.

2.

UFSAR, Chapter 15.

3.

UFSAR, Section 5.2.

4.

ASME Code for Operation and Maintenance of Nuclear Power Plants.

5.

10 CFR 50.36, Technical Specifications, {c)(2)(ii). ~~c.1' '"it'"~Tll\\)C7 P1Lo00J - --- Catawba Units 1 and 2 B 3.4.10-4 Revision No:r2-

BASES LTOP System B 3.4.12 SURVEILLANCE SR 3.4.12.1 and SR 3.4.12.2 REQUIREMENTS To minimize the potential for a low temperature overpressure event by limiting the mass input capability, a maximum of two pumps (charging and/or safety injection) are verified capable of injecting into the RCS and the accumulator discharge isolation valves are verified closed and power removed. The pumps are rendered incapable of injecting into the RCS through removing the power from the pumps by racking the breakers out under administrative control. An alternate method of L TOP control may be employed using at least two independent means to prevent a pump start such that a single failure or single action will not result in an injection into the RCS. This may be accomplished through two valves in the discharge flow path being closed. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.4.12.3 Each required RHR suction relief valve shall be demonstrated OPERABLE by verifying its RH R uction isolation valves are o en and b testing it in accordance with th . This Surveillance is only required to be performed if the RHR suction relief valve is being used to meet this LCO. The RHR suction isolation valves are verified to be opened. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. The ASME Code (Ref. 9), test pe~ erifies OPERABILITY by proving relief valve mechanical motion and by measuring and, if required, adjusting the lift setpoint. -l'1 e t.AJS f J!.V 1c.E -rc-$711J6 ~ UX:,.i Aµ SR 3.4.12.4 The PORV block valve must be verified open to provide the flow path for each required PORV to perform its function when actuated. The valve must be remotely verified open in the main control room. This Surveillance is performed if the PORV satisfies the LCO. The block valve is a remotely controlled, motor operated valve. The Catawba Units 1 and 2 B 3.4.12-12 Revision No. BASES LTOP System B 3.4.12 SURVEILLANCE REQUIREMENTS (continued) REFERENCES SR 3.4.12.7 The RHR suction isolation valves are verified open, with power to the valve operator removed and locked in the removed position, to ensure that accidental closure will not occur. The "locked open in the removed position" power supply must be locally verified in its open position with the power supply to the valve locked in its inactive position. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

1.

10 CFR 50, Appendix G.

2.

Generic Letter 88-11.

3.

UFSAR, Section 5.2

4.

10 CFR 50, Section 50.46.

5.

10 CFR 50, Appendix K.

6.

10 CFR 50.36, Technical Specifications, (c){2)(ii).

7.

Generic Letter 90-06.

8.

ASME, Boiler and Pressure Vessel Code, Section Ill.

9.

ASME Code for Operation and Maintenance of Nuclear Power Plants. Catawba Units 1 and 2 B 3.4.12-14 Revision No. -S--

BASES ECCS - Operating B 3.5.2 SURVEILLANCE REQUIREMENTS (continued) gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met. Accumulated gas should be eliminated or brought within the acceptance criteria limits. ECCS locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-set of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations and trending of the results should be sufficient to assure system OPERABILITY during the Surveillance interval. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. The Surveillance Frequency may vary by location susceptible*to gas accumulation. SR 3.5.2.4 Periodic surveillance testing of ECCS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the ASME Code. This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve. This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater than or equal to the performance assumed in the plant safety analysis. SRs are specified in th I the ASME Code. e A o e provides the activities and Frequencies necessary to satisfy the requirements. Catawba Units 1 and 2 B 3.5.2-9 Revision No.4-

BASES Containment Isolation Valves B3.6.3 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.3.5 Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY. The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analyses. The isolation time is specified in the UFSAR and the Frequency of this SR is in accordance with th SR 3.6.3.6 For the Containment Purge System valves with resilient seals, additional leakage rate testing beyond the test requirements of 1 O CFR 50, Appendix J, Option B is required to ensure OPERABILITY. The measured leakage rate for the Containment Purge System and Hydrogen Purge System valves must be~ 0.05 La when pressurized to Pa. Operating experience has demonstrated that this type of seal has the potential to degrade in a shorter time period than other seal types. Based on this observation and the importance of maintaining this penetration leak tight (due to the direct path between containment and the environment), these valves will not be placed on the maximum extended test interval. Therefore, these valves will be tested in accordance with Regulatory Guide 1.163, which allows a maximum test interval of 30 months. The Containment Air Release and Addition System valves have a demonstrated history of acceptable leakage. The measured leakage rate for containment air release and addition valves must be,=:. 0.01 La when pressurized to P ** These valves will be tested in accordance with Regulatory Guide 1.163, which allows a maximum test interval of 30 months. SR 3.6.3.7 Automatic containment isolation valves close on a containment isolation signal to prevent leakage of radioactive material from containment following a OBA. This SR ensures that each automatic containment isolation valve will actuate to its isolation position on a containment Catawba Units 1and2 B 3.6.3-13 Revision No..4-

BASES Containment Spray System 8 3.6.6 SURVEILLANCE REQUIREMENTS (continued) performance required by the ASME Code (Ref. 6). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice inspections confirm component OPERABILITY. trend performance, and detect incipient failures by indicating abnormal ~rformance. The Frequency of this SR is in accordance with the r;:;;;;af¥iea +esliAg JS1e;l'9~ i m ew1 cr~11Nf.> I'.#X::JJ!_A""' SR 3.6.6.3 and SR 3.6.6.4 Not used. SR 3.6.6.5 and SR 3.6.6.6 These SRs require verification of proper interaction between the CPCS system and the Containment Spray System. SR 3.6.6.5 deals solely with the containment spray pumps. It must be shown through testing that: (1) the containment spray pumps are prevented from starting in the absence of a CPCS permissive. (2) the containment spray pumps can be manually started when given a CPCS permissive, and (3) when running, the containment spray pumps stop when the CPCS permissive is removed. The "inhibit". "permit, and "terminate" parts of the CPCS interface with the containment spray pumps are verified by testing in this fashion. SR 3.6.6.6 deals solely with containment spray header containment isolation valves NS12B, NS15B, NS29A. and NS32A. It must be shown through testing that: ( 1) each valve closes when the CPCS permissive is removed, OR (2) each valve is prevented from opening in the absence of a CPCS permissive. In addition to one of the above, it must also be shown that each valve can be manually opened when given a CPCS permissive. The Surveillance Frequency is based on operating experience. equipment rellabit\\ty, and ptant r'sk and \\s control\\ed under the Surveillance Frequency Control Program. Catawba Units 1 and 2 B 3.6.6-6 Revision No...:f-

BASES MSSVs 83.7.1 APPLICABLE SAFETY ANALYSES (continued) LCO APPLICABILITY For the peak secondary pressure case, the reactor is tripped on overtemperature AT. Pressurizer relief valves and MSSVs are activated and prevent overpressurization in the primary and secondary systems. The MSSVs satisfy Criterion 3of10 CFR 50.36 (Ref. 4). The accident analysis assumes five MSSVs per steam generator to provide overpressure protection for design basis transients occurring at 3479 MWt. An MSSV will be considered inoperable if it fails to open on demand. The LCO requires that five MSSVs be OPERABLE in compliance with Reference 2, even though this is not a requirement of the OBA analysis. This is because operation with less than the full number of MSSVs requires limitations on allowable THERMAL POWER (to meet ASME Code requirements). These limitations are according to Table 3.7.1-1 in the accompanying LCO, and Required Action A.1 and A.2. The OPERABILITY of the MSSVs is defined as the ability to open within the setpoint tolerances, relieve steam generator overpressure, and reseat when pressure has been reduced. The OPERABILITY of the MSSVs is d rmined b ri ic rveillance testing in accordance with the The lift settings, according to Table 3.7.1-2 in the accompanying LCO, correspond to ambient conditions of the valve at nominal operating temperature and pressure. This LCO provides assurance that the MSSVs will perform their designed safety functions to mitigate the consequences of accidents that could result in a challenge to the RCPB. In MODE 1. the number of MSSVs per steam generator required to be OPERABLE must be according to Table 3.7.1-1 in the accompanying LCO. In MODES 2 and 3, only two MSSVs per steam generator are required to be OPERABLE. In MODES 4 and 5, there are no credible transients requiring the MSSVs. The steam generators are not normally used for heat removal in MODES 5 and 6, and thus cannot be overpressurized; there is no requirement for the MSSVs to be OPERABLE in these MODES. Catawba Units 1 and 2 B 3.7.1-2 Revision No.4-

BASES MSSVs B3.7.1 ACTIONS (continued) B.1 and B.2 If the MSSVs cannot be restored to OPERABLE status within the associated Completion Time, or if one or more steam generators have less than two MSSVs OPERABLE, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience. to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.1.1 REQUIREMENTS e Code (Ref. 6), requires that safety and relief valve tests be performed. According to Reference 6, the following tests are required:

a.

Visual examination;

b.

Seat tightness determination;

c.

Setpoint pressure detennination (lift setting};

d.

Compliance with seat tightness criteria; and

e.

Verification of the balancing device integrity on balanced valves. All valves are required to be tested every 5 years, and a minimum of 20% of the valves are required to be tested every 24 months. The ASME Code specifies the activities and frequencies necessary to satisfy the requirements. Table 3. 7.1-2 allows a+/- 3% setpoint tolerance for OPERABILITY; however, the valves are reset to +/- 1 % during the Surveillance to allow for drift. This SR is modified by a Note that allows entry Into and operation in MODE 3 prior to performing the SR. The MSSVs may be either bench tested or tested in situ at hot conditions using an assist device to simulate lift pressure. If the MSSVs are not tested at hot conditions, the lift setting pressure shall be corrected to ambient conditions of the valve at operating temperature and pressure. Catawba Units 1 and 2 83.7.1-4 Revision No.+-

BASES MS IVs 83.7.2 SURVEILLANCE REQUIREMENTS (continued) REFERENCES is SR is normally performed upon returning um operation following a refueling outage. The MSIVs should not be tested at power, since even a part stroke exercise increases the risk of a valve closure when the unit is generating power. As the MSIVs are not tested at power, they are exempt from the ASME Code (Ref. 6), requirements during operation in MODE 1 or 2. The Frequency is in accordance with th This test is conducted in MODE 3 with the unit at operating temperature and pressure, as discussed in Reference 6 exercising requirements. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR. This allows a delay of testing until MODE 3, to establish conditions consistent with those under which the acceptance criterion was generated.

1.

UFSAR, Section 10.3.

2.

UFSAR, Section 6.2.

3.

UFSAR, Section 15.1. 5.

4.

10 CFR 50.36, Technical Specifications, (c)(2)(ii).

5.

10 CFR 50.67.

6.

ASME Code for Operation and Maintenance of Nuclear Power Plants. Catawba Units 1 and 2 B 3.7.2-5 Revision No.-a--

BASES MFIVs, MFCVs, Associated Bypass Valves and Tempering Valves 83.7.3 ACTIONS (continued) SURVEILLANCE REQUIREMENTS judgment, in view of valve status indications available in the control room, and other administrative controls, to ensure that these valves are closed or isolated. With the tempering valve inoperable or two inoperable valves in the same flow path, there may be no redundant system to operate automatically and perform the required safety function. The tempering valves have no other automatic isolation valves in series to provide isolation. Under these conditions, affected valves in each flow path must be restored to OPERABLE status, or the affected flow path isolated within 8 hours. This action returns the system to the condition where at least one valve in each flow path is performing the required safety function. The 8 hour Completion Time is reasonable, based on operating experience, to complete the actions required to close the MFIV or MFCV, or otherwise isolate the affected flow path. E.1 and E.2 If the MFIV(s), MFCV(s), and the associated bypass valve(s) or the tempering valve(s) cannot be restored to OPERABLE status, or closed, or isolated within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SR 3.7.3.1 This SR verifies that the closure time of each MFIV, MFCV, and associated bypass valves, and the tempering valve is s 12 seconds on an actual or simulated actuation signal. The MFIV and MFCV closure times are assumed in the accident and containment analyses. This SR also verifies the valve closure time is in accordance with th his SR is normally performed upon returning e unit to --__.::::;~ operation following a refueling outage. These valves should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. This is consistent with the Cstawba Units 1 and 2 B 3.7.3-5 Revision No BASES MFIVs, MFCVs, Associated Bypass Valves and Tempering Valves 83.7.3 SURVEILLANCE REQUIREMENTS (continued) REFERENCES ASME Code (Ref. 3), quarterly stroke requirements during operation In MODES 1 and 2.

1.

UFSAR, Section 10.4. 7.

2.

10 CFR 50.36, Technical Specifications, (c)(2)(ii).

3.

ASME Code for Operation and Maintenance of Nuclear Power Plants. Catawba Units 1 and 2 B 3.7.3-6 Revision No.-2--

BASES AFWSystem B 3.7.5 ACTIONS (continued) E.1 SURVEILLANCE REQUIREMENTS In MODE 4, either the reactor coolant pumps or the RHR loops can be used to provide forced circulation. This is addressed in LCO 3.4.6, "RCS Loops-MODE 4." With one required AFW train inoperable, action must be taken to immediately restore the inoperable train to OPERABLE status. The immediate Completion Time is consistent with LCO 3.4.6. SR 3.7.5.1 Verifying the correct alignment for manual, power operated, and automatic valves in the AFW System water and steam supply flow paths provides assurance that the proper flow paths will exist for AFW operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified to be in the correct position prior to locking, sealing, or securing. This SR also does not apply to valves that cannot be inadvertently misaligned, such as check valves. This Surveillance does not require any testing or valve manipulation: rather, it involves verification that those valves capable of being mispositioned are in the correct position. The SR is also modified by a note that excludes automatic valves when THERMAL POWER is ,::. 10% RTP. Some automatic valves may be in a throttled position to support low power operation. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.7.5.2 Verifying that each AFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that AFW pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref. 3). Because it is undesirable to introduce cold AFW into the steam generators while they are operating, this testing is performed on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. ormance of inservtce es sssed in the ASME Code (Ref. 3) c: (peW f!'!1.1ir:eiit I iii>rit~ inii~ tlsfies this requirement. Catawba Units 1 and 2 B 3.7.5-7 Revision No..a-

8 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY BASES SRs SR 3.0.1 SR 3.0.1 through SR 3.0.5 establish the general requirements applicable to all Specifications and apply at all times, unless otherwise stated. SR 3.0.1 establishes the requirement that SRs must be met during the MODES or other specified conditions in the Applicability for which the requirements of the LCO apply. unless otherwise specified in the individual SRs. This Specification is to ensure that Surveillances are performed to verify the OPERABILITY of systems and components, and that variables are within specified limits. Failure to meet a Surveillance within the specified Frequency. in accordance with SR 3.0.2, constitutes a failure to meet an LCO. Systems and components are assumed to be OPERABLE when the associated SRs have been met. Nothing in this Specification, however. is to be construed as implying that systems or components are OPERABLE when:

a.

The systems or components are known to be inoperable, although still meeting the SRs; or

b.

The requirements of the Surveillance(s) are known not to be met between required Surveillance performances. Surveillances do not have to be performed when the unit is in a MODE or other specified condition for which the requirements of the associated LCO are not applicable, unless otherwise specified. The SRs associated with a test exception are only applicable when the test exception is used as an allowable exception to the requirements of a Specification. Unplanned events may satisfy the requirements (including applicable acceptance criteria) for a given SR. In this case, the unplanned event may be credited as fulfilling the performance of the SR. This allowance includes those SRs whose performance is normally precluded in a given MODE or other specified condition. Surveillances, including Surveillances invoked by Required Actions, do not have to be performed on inoperable equipment because the ACTIONS define the remedial measures that apply. Surveillances have to be met and performed in accordance with SR 3.0.2, prior to returning equipment to OPERABLE status. McGuire Units 1 and 2 B 3.0-11 Revision No.-.e+

BASES SR Applicability B 3.0 SURVEILLANCE REQUIREMENT {continued) SR 3.0.2 ti f'1 M ~ ~ ~ VJ ~ ~ '5, /"'\\ ~ r'\\ ca ~ ~~ ~ ~ ~ i ~ ~ ~ ~ ~ Upon completion of maintenance, appropriate post maintenance testing is required to declare equipment OPERABLE..This includes ensuring applicable Surveillances are not failed and their most recent performance is in accordance with SR 3.0.2. Post maintenance testing may not be possible in the current MODE or other specified conditions in the Applicability due to the necessary unit parameters not having been established. In these situations. the equipment may be considered OPERABLE provided testing has been satisfactorily completed to the extent possible and the equipment is not otherwise betieved to be incapable of performing its function. This will allow operation to proceed to a MODE or other specified condition where other necessary post maintenance tests can be completed. SR 3.0.2 establishes the requirements for meeting the specified Frequency for Surveillances and any Required Action with a Completion Time that requires the periodic performance of the Required Action on a "once per... "interval. SR 3.0.2 permits a 25% extension of the interval specified in the Frequency. This extension facilitates Surveillance scheduling and considers plant operating conditions that may not be suitable for conducting the Surveillance (e.g., transient conditions or other ongoing Surveillance or maintenance activities}. The 25% extension does not significantly degrade the reliability that results from performing the Surveillance at its specified Frequency. This is based on the recognition that the most probable result of any particular Surveilla ein erformed is the verification of conformance with the SRs. he exceptions to .. are ose urve1 lances for wh1 25% extension of the interval specified in the Frequency ot apply. These exceptions are stated in the individual S rans. The requirements of regulations take d ver the TS. An example of where SR 3. oes not apply is in the Containment gram. This program establishes testing requirements an uencies in accordance with requirements of regulatio e TS cannot in and of themselves extend a test interval o.ec~k:I in regulations. As stated in SR 3.0.2, the 25% extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a McGuire Units 1 and 2 B 3.0-12 Revision No..at-

INSERT 1 MNS Bases SR 3.0.2 When a Section 5.5, "Programs and Manuals," specification states that the provisions of SR 3.0.2 are applicable, a 25% extension of the testing interval, whether stated in the specification or incorporated by reference, is permitted. INSERT 2 MNS Bases SR 3.0.2 The exceptions to SR 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply. These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS. Examples of where SR 3.0.2 does not apply are the Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the inservice testing of pumps and valves in accordance with applicable American Society of Mechanical Engineers Operation and Maintenance Code, as required by 10 CFR 50.55a. These programs establish testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot, in and of themselves, extend a t~st interval specified in the regulations directly or by reference.

BASES SR Applicability B 3.0 SURVEILLANCE REQUIREMENT (continued) SR 3.0.3 "once per... " basis. The 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or the action accomplishes the function of the inoperable equipment in an alternative manner. The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified. SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours or up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the Surveillance has not been pet1ormed in accordance with SR 3.0.2, and not at the time --=---that the specified Frequency was not met. This delay period provides adequate time to complete Surveillances that have been missed. This delay period permits the completion of a Surveillance before complying with Required Actions or other remedial measures that might preclude completion of the Surveillance. The basis for this delay period includes consideration of unit conditions, adequate planning, availability of personnel, the time required to perform the Surveillance, the safety significance of the delay in completing the required Surveillance, and the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the requirements. When a Surveillance with a Frequency based not on time intervals, but upon specified unit conditions, operating situations, or requirements of regulations (e.g., prior to entering MODE 1 after each fuel loading, or in accordance with 10 CFR 50, Appendix J, as modified by approved exemptions, etc.) is discovered to not have been performed when specified, SR 3.0.3 McGuire Units 1 and 2 B 3.0-13 Revision No.-8+

INSERT MNS Bases SR 3.0.3 When a Section 5.5, "Programs and Manuals, 11 specification states that the provisions of SR 3.0.3 are applicable, it permits the flexibility to defer declaring the testing requirement not met in accordance with SR 3.0.3 when the testing has not been completed within the testing interval (including the allowance of SR 3.0.2 if invoked by the Section 5.5 specification).

BASES Pressurizer Safety Valves B 3.4.10 ACTIONS (continued) 8.1 and B.2 If the Required Action of A. 1 cannot be met within the required Completion Time or if two or more pressurizer safety valves are inoperable. the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 4 with any RCS cold leg temperatures s 300°F within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. With any RCS cold leg temperatures at or below 300°F, overpressure protection is provided by the LTOP System. The change from MODE 1, 2, or 3 to MODE 4 reduces the RCS energy (core power and pressure), lowers the potential for large pressurizer insurges, and thereby removes the need for overpressure protection by three pressurizer safety valves. SURVEILLANCE SR 3.4.10.1 REQUIREMENTS REFERENCES SRs are specified in t . Pressurizer safety valves are to be teS m accordance e requirements of the ASME OM Code (Ref. 4), which provides the activities and Frequencies necessary to satisfy the SRs. No additional requirements are specified. The pressurizer safety valve setpoint is + 3% and - 2% of the nominal setpoint of 2485 psig for OPERABILITY; however, the valves are reset to +/- 1 % during the Surveillance to allow for drift.

1.

ASME, Boiler and Pressure VesseJ Code, Section Ill.

2.

UFSAR, Chapter 15.

3.

UFSAR Section 5.2.

4.

ASME Code for Operation and Maintenance of Nuclear Power Plants.

5.

10 CFR 50.36, Technical Specifications, (c)(2)(ii). , tvJ e:w, a -re..sr / N l> PILO &~A,vt McGuire Units 1 and 2 B 3.4.10-4 Revision No. 4Q2-

BASES ECCS-Operating B 3.5.2 SURVEILLANCE REQUIREMENTS (continued) or securing. A valve that receives an actuation signal is allowed to be in a nonaccident position provided the valve will automatically reposition within the proper stroke time. This Surveillance does not require any testing or valve manipulation. Rather, it involves verification that those valves capable of being mispositioned are in the correct position. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.5.2.3 ECCS piping is verified to be water-filled by venting to remove gas from accessible locations susceptible to gas accumulation. Alternative means may be used to verify water-filled conditions (e.g., ultrasonic testing or high point sightglass observation). Maintaining the ECCS pumps and piping full of water ensures that the system will perform properly, injecting its full capacity into the RCS upon demand. This will also prevent water hammer, pump cavitation, and pumping of noncondensible gas (e.g., air, nitrogen, or hydrogen) into the reactor vessel following an SI signal or during shutdown cooling. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.5.2.4 Periodic surveillance testing of ECCS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the ASME OM Code. This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve. This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater n or ual to the rformance assu lant safety analysis. SRs are specified in which encompasses the ASME OM Code. The ASME Code prov1 es e activities and Frequencies necessary to satisfy the requirements. McGuire Units 1 and 2 83.5.2-8 Revision No. -+1&-

BASES Containment Isolation Valves 83.6.3 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.3.4 This SR requires verification that each containment isolation manual valve and blind flange located inside containment or annulus and not locked, sealed, or otherwi~e secured and required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the containment boundary is within design limits. For containment isolation valves inside containment, the Frequency of "prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days" is appropriate since these containment isolation valves are operated under administrative controls and the probability of their misalignment is low. The SR specifies that containment isolation valves that are open under administrative controls are not required to meet the SR during the time they are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be the correct position upon lockjng, sealing, or securing. This Note allows valves and blind flanges located in high radiation areas to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3, and 4, for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verifted to be in their proper position, is small. SR 3.6.3.5 Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY. The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analyses. The isolation time is speci.. fi. ~~ed;se;in~th~e;U~FitSiAR~a~nrodmF~uency of this SR are in accordance with that 'P'F----------=-__..;::.__, McGuire Units 1 and 2 B 3.6.3-11 Revision No. 446-

BASES Containment Spray System 83.6.6 ACTIONS {continued) B.1and8.2 SURVEILLANCE REQUIREMENTS McGuire Unit 1 and 2 If the affected containment spray train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 84 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. The extended interval to reach MODE 5 allows additional time and is reasonable when considering that the driving force for a release of radioactive material from the Reactor Coolant System Is reduced in MODE3. SR 3.6.6.1 Verifying the correct alignment of manual and power operated valves, excluding check valves, in the Containment Spray System provides assurance that the proper flow path exists for Containment Spray System operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since they were verified in the correct position prior to being secured. This SR does not require any testing or valve manipulation. Rather, it involves verification, through a system walkdown or computer status indication, that those valves outside containment and capable of potentially being mispositioned, are in the correct position. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. The surveillance includes verifying the correct alignment of the containment spray pump discharge valves. SR 3.6.6.2 Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME OM Code (Ref. 6). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by Indicating abnormal rfo . T F uency of this SR is in accordance with t B 3.6.6-5 Revision No. 4 98

BASES MSSVs B3.7.1 APPLICABLE SAFETY ANALYSES (continued) LCO APPLICABILITY For the peak secondary pressure case, the reactor is tripped on overtemperature aT. Pressurizer relief valves and MSSVs are activated and prevent overpressurization in the primary and secondary systems. The MSSVs satisfy Criterion 3of10 CFR 50.36 {Ref. 4). The accident analysis assumes five MSSVs per steam generator to provide overpressure protection for design basis transients occurring at 3479 MWt An MSSV will be considered inoperable if it fails to open on demand. The LCO requires that five MSSVs be OPERABLE in compliance with Reference 2, even though this is not a requirement of the OBA analysis. This is because operation with less than the full number of MSSVs requires limitations on allowable THERMAL POWER (to meet ASME Code requirements). These limitations are according to Table 3.7.1-1 in the accompanying LCO, and Required Action A.1 and A.2. The OPERABILITY of the MSSVs is defined as the ability to open within the setpoint tolerances, relieve steam generator overpressure, and reseat when pressure has been reduced. The OPERABILITY of the MSSVs is determined b riodic surveillance testing in accordance with IA1ePJice l=eetiAg The lift settings, according to Table 3. 7.1-2 in the accompanying LCO, correspond to ambient conditions of the valve at nominal operating temperature and pressure. This LCO provides assurance that the MSSVs will perform their designed safety functions to mitigate the consequences of accidents that could result in a challenge to the RCPB. In MODE 1 t the number of MSSVs per steam generator required to be OPERABLE must be according to Table 3. 7.1-1 in the accompanying LCO. In MODES 2 and 3, only two MSSVs per steam generator are required to be OPERABLE. In MODES 4 and 5, there are no credible transients requiring the MSSVs. The steam generators are not normally used for heat removal in MODES 5 and 6, and thus cannot be overpressurized; there is no requirement for the MSSVs to be OPERABLE in these MODES. McGuire Units 1 and 2 B 3.7.1-2 Revision No. -429--

BASES MSSVs B 3.7.1 ACTIONS (continued) B.1 and B.2 If the MSSVs cannot be restored to OPERABLE status within the associated Completion Time, or if one or more steam generators have less than two MSSVs OPERABLE, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.1.1 REQUIREMENTS This SR verifies the OPERABILITY of the MSSVs by the ve

h MSSV lift setpoint in accordance with the

-IA The ASME OM Code (Ref. 5) requires a s e an re 1e va ve tests be performed. According to Reference 5, the following tests are required:

a.

Visual examination;

b.

Seat tightness determination;

c.

Setpoint pressure determination (lift setting);

d.

Compliance with seat tightness criteria; and

e.

Verification of the balancing device integrity on bafanced valves. The ASME Standard requires that all valves be tested every 5 years, and a minimum of 20% of the valves be tested every 24 months. The ASME OM Code specifies the activities and frequencies necessary to satisfy the requirements. Table 3.7.1-2 allows a :t 3% setpoint tolerance for OPERABILITY; however, the valves are reset to +/- 1 % during the Surveillance to allow for drift. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR. The MSSVs may be either bench tested or tested in situ at hot conditions using an assist device to simulate lift pressure. If the MSSVs are not tested at hot conditions, the lift setting pressure shall be corrected to ambient conditions of the valve at operating temperature and pressure. McGuire Units 1 and 2 B 3.7.1-4 Revision No. 429-

BASES ACTIONS (contd) Q.1and0.2 MS IVs 83.7.2 If the MSIVs cannot be restored to OPERABLE status or are not closed within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed at least in MODE 3 within 6 hours, and in MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from MODE 2 conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.2.1 REQUIREMENTS REFERENCES This SR verifies that MSIV closure time is s 8.0 seconds on an actual or simulated actuation signal. The MSIV closure time is assumed in the accident and containment analyses. This Surveillance is normally performed during a refueling outage. The MSIVs should not be tested at power, since even a part stroke exercise increases the risk of a valve closure when the unit is generating power. An IST program Justification For Deferral documents the basis for performing the stroke time testing during cold shutdown instead of at ower. This alternative is acceptable in accordance with the nd the ASME OM Code (Ref. 5). The Frequency is in accordance with t Separate A and B train tests are conducted at cold condition to meet the requirements of the ASME OM Code. These tests shall be performed with both spring force and the motive force provided by Instrument Air (VI) simultaneously. Leak-rate testing of the MSIV air control system shall be performed prior to retumi11g the unit to operation followin,g a refueling outage. A final test is conducted in MODE 3 with the unit at operating temperature and pressure (ref. NRC Information Notice 94-44). This test also shall be performed with both spring force and the motive force provided by the Instrument Air (VI) simultaneously. This final test verifies MSIV closure time remains acceptable at system conditions consistent with those under which the MSIV is required to operate. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing this finer test

1.

UFSAR, Section 10.3.

2.

UFSAR, Section 6.2. McGuire Units 1 and 2 83.7.2-5 Revision49i-

BASES MFIVs, MFCVs, MFCV's Bypass Valves, and MFW/AFW NBVs 83.7.3 ACTIONS (continued) 0.1 With two inoperable valves in the same flow path, there may be no redundant system to operate automatically and perform the required safety function. Under these conditions, affected valves in each flow path must be restored to OPERABLE status, or the affected flow path isolated within 8 hours. This action returns the system to the condition where at least one valve in each flow path is performing the required safety function. The 8 hour Completion Time is reasonable, based on operating experience, to complete the actions required to close the MFIV or MFCV, or otherwise isolate the affected flow path. E.1 and E.2 If the MFIV(s), MFCV(s), MFCV's bypass valve(s), and MFW/AFW NBV(s) cannot be restored to OPERABLE status, or closed, or isolated within the associated Completion Time, the unit must be placed in a MODE In which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience. to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3. 7.3.1 REQUIREMENTS This SR verifies that the closure time of each MFIV, MFCV, MFCV's bypass valve, and MFW/AFW NBV is s 10 seconds on an actual or simulated actuation signal. The MFIV and MFCV closure times are assumed in the ac.cident and containment analyses. This Surveillance is normally performed upon returning the unit to operation following a refueling outage. These valves should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. This is consistent with the ASME OM Code (Ref. 3) quarterly stroke requirements during operation in MODES 1 and 2. McGuire Units 1 and 2 B 3.7.3-5 Revision No.~

BASES AFWSystem B 3.7.5 SURVEILLANCE REQUIREMENTS (continued) The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.7.5.2 Verifying that each AFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that AFW pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME OM Code (Ref 3). Because it is undesirable to introduce cold AFW into the steam generators while they are operating, this testing is performed on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend rformance, and detect incipient fail res b indicating abnormal performance. e orm nee o enservice testin iscussed in the ASME OM Code (Ref. 3 satisfies this requirement. (J;g~;:i'tifQr llli9 SR j9 iH aaseraaAc:a wjtb the:iiiiiefViee T~ This SR is modified by a Note indicating that the SR should be deferred until suitable test conditions are established. This deferral is required because there is insufficient steam pressure to perform the test. The test should be conducted within 24 hours of the steam pressure exceeding 900 psig. SR 3.7.5.3 This SR verifies that AFW can be delivered to the appropriate steam generator in the event of any accident or transient that generates an ESF AS, by demonstrating that each automatic valve in the flow path actuates to its correct position on an actual or simulated actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. This SR is modified by a Note that states the SR is not required in MODE 4. In MODE 4, the required AFW train may already be aligned and operating. McGuire Units 1 and 2 B 3.7.5-7 Revision No. 44i- ---~-

SR Applicability B 3.0 B 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY BASES SRs SR 3.0.1 through SR 3.0.4 establish the general requirements applicable to all Specifications and apply at all times, unless otherwise stated. SR 3.0.1 SR 3.0.1 establishes the requirement that SRs must be met during the MODES or other specified conditions in the Applicability for which the requirements of the LCO apply, unless otherwise specified in the individual SRs. This Specification is to ensure that Surveillances are performed to verify the OPERABILITY of systems and components, and that variables are within specified limits. Failure to meet a Surveillance within the specified Frequency, in accordance with SR 3.0.2, constitutes a failure to meet an LCO. Systems and components are assumed to be OPERABLE when the associated SRs have been met. Nothing in this Specification, however, is to be construed as implying that systems or components are OPERABLE when:

a.

The systems or components are known to be inoperable, although still meeting the SRs; or

b.

The requirements of the Surveillance{s) are known to be not met between required Surveillance perfonnances. Surveillances do not have to be performed when the unit is in a MODE or other specified condition for which the requirements of the associated LCO are not applicable, unless otherwise specified. The SRs associated with an Exception LCO are only applicable when the Exception LCO is used as an allowable exception to the requirements of a Specification. Unplanned events may satisfy the requirements {including applicable acceptance criteria) for a given SR. In this case, the unplanned event may be credited as fulfilling the perfonnance of the SR. This allowance includes those SRs whose performance is normally precluded in a given MODE or other specified condition. Surveillances, including Surveillances invoked by Required Actions, do not have to be performed on inoperable equipment because the ACTIONS OCONEE UNITS 1, 2, & 3 8 3.0-11 Amendment Nos. 958, 358, & 951 I

BASES SR 3.0.1 (continued) SR 3.0.2 SR Applicability B 3.0 define the remedial measures that apply. Surveillances have to be met and performed in accordance with SR 3.0.2, prior to returning equipment to OPERABLE status. Upon completion of maintenance, appropriate post maintenance testing is required to declare equipment OPERABLE. This includes ensuring applicable Surveillances are not failed and their most recent performance is in accordance with SR 3.0.2. Post maintenance testing may not be possible in the current MODE or other specified conditions in the Applicability due to the necessary unit parameters not having been established. \\n these situations, the equipment may be considered OPERABLE provided testing has been satisfactorily completed to the extent possible and the equipment is not otherwise believed to be incapable of performing its function. This will allow operation to proceed to a MODE or other specified condition where other necessary post maintenance tests can be completed. Some example of this process are:

a.

Emergency feedwater (EFW) pump turbine maintenance during refueling that requires testing at steam pressures> 300 psi. However, if other appropriate testing is satisfactorily completed, the EFW System can be considered OPERABLE. This allows startup and other necessary testing to proceed while the plant reaches the steam pressure required to perform the EFW pump testing.

b.

High Pressure Injection (HPI) maintenance during shutdown that requires system functional tests at a specified pressure. Provided other appropriate testing is satisfadorily completed, startup can proceed with HPI considered OPERABLE. This allows operation to reach the specified pressure to complete the necessary post maintenance testing. SR 3.0.2 establishes the requirements for meeting the specified Frequency for Surveillances and any Required Action with a Completion Time that requires the periodic performance of the Required Action on a "once per... " interval. SR 3.0.2 permits a 25% extension of the interval specified in the Frequency. This extension facilitates Surveillance scheduling and considers plant operating conditions that may not be suitable for conducting the Surveillance (e.g., transient conditions or other ongoing Surveillance or maintenance activities). OCONEE UNITS 11 2, & 3 B 3.0-12 Amendment Nos. '958, ase, & 357 I

BASES SR 3.0.2 (continued) SR 3.0.3 SR Applicability B 3.0 The 25% extension does not significantly degrade the reliability that results from performing the Surveillance at its specified Frequency. This is based on the recognition that the most probable result of any particular Surveillance bein e verification of confonnance with the SRs. The exceptions to SR 3.0.2 are those Surveillances for w 1c 5 o extension of the interval specified in the Frequency d apply. These exceptions are stated in the in * *dual S ons. The requirements of regulations take p11 over the TS. An example of where SR 3.0.2 does not ap

in the Containment Leakage Rate Testing Program. Thi gram establishes testing requirements and Frequencies
rdance with the requirements of regulations. The TS cannot i a of themselves extend a test interval specified in the reA4cnat1' ons.

As stated in SR 3.0.2, the 25% extension also does not apply to the initial portion of a periodic Completion Time that requires perfonnance on a "once per... "basis. The 25% extension applies to each performance after the initial performance. The initial perfonnance of the Required Adion, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or accomplishes the function of the inoperable equipment in an alternative manner. The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified. SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours or up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the Surveillance has not been performed in accordance with SR 3.0.2, and not at the time that the specified Frequency was not met. This delay period provides an adequate time to complete Surveillances that have been missed. This delay period pennits the completion of a Surveillance before complying with Required Actions or other remedial measures that might preclude completion of the Surveillance. OCONEE UNITS 1, 2, & 3 8 3.0-13 BASES REVISION DATED'1~2&111 I

INSERT 1 CNS Bases SR 3.0.2 When a Section 5.5, "Programs and Manuals," specification states that the provisions of SR 3.0.2 are applicable, a 25% extension of the testing interval, whether stated in the specification or incorporated by reference, is permitted. INSERT 2 CNS Bases SR 3.0.2 The exceptions to SR 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply. These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS. Examples of where SR 3.0.2 does not apply are the Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the inservice testing of pumps and valves in accordance with applicable American Society of Mechanical Engineers Operation and Maintenance Code, as required by 10 CFR 50.55a. These programs establish testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot, in and of themselves, extend a t~st interval specified in the regulations directly or by reference.

INSERT ONS Bases SR 3.0.3 When a Section 5.5, "Programs and Manuals," specification states that the provisions of SR 3.0.3 are applicable, it permits the flexibility to defer declaring the testing requirement not met in accordance with SR 3.0.3 when the testing has not been completed within the testing interval (including the allowance of SR 3.0.2 if invoked by the Section 5.5 specification).

BASES (continued) REFERENCES SR 3.4.10.1 Pressurizer Safety Valves B 3.4.10 el tfll98F¥161~stiQG-fiZRJareffl. Pressurizer safety valves are to be tested in ance Wt e requirements of the ASME Code (Ref. 2), which provides the activities and the Frequency necessary to satisfy the SRs. No additional requirements are specified. The pressurizer safety valves setpoint is +/- 3% for OPERABILITY: however, the valves are reset to +/-1 % during the Surveillance to allow for drift These values include instrument uncertainties.

1.

ASME, Boiler and Pressure Vessel Code, Section Ill.

2.

ASME Code for Operation and Maintenance of Nuclear Power Plants.

3.

10 CFR 50.36. OCONEE UNITS 1, 2, & 3 B 3.4.1()..4 Rev.-994-I

BASES SURVEILLANCE REQUIREMENTS (continued) SR 3.5.2.3 HPI B 3.5.2 Periodic surveillance testing of HPI pumps to detect gross degradation caused by Impeller structural damage or other hydraulic component blems ls uired the ASME Code (Ref. 5). SRs are specified in the -1A88f¥t~~-f'IN9191ft\\gUD~-~~e. SR 3.5.2.4 and SR 3.5.2.5 These SRs demonstrate that each automatic HPI valve actuates to the required position on an actual or simulated ESPS signal and that each HPI pump starts on receipt of an actual or simulated ESPS signal. This SR is not required for valves that are locked, sealed, or otherwise secured In position under administrative controls. The test will be considered satisfactory if control board indication verifies that all components have responded to the ESPS actuation signal properly (all appropriate ESPS actuated pump breakers have opened or closed and all ESPS actuated valves have completed their travel). The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. The actuation logic is tested as part of the ESPS testi and e ui ment performance is monitored as part of SR 3.5.2.6 Periodic inspections of the reactor building sump suction inlet (for LPl-HPI flow path) ensure that it is unrestricted and stays in proper operating condition. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.5.2.7 Periodic stroke testing of the HPI discharge crossover valves (HP-409 and HP-410) and LPl-HPI flow path discharge valves (LP-15 and LP-16) Is required to ensure that the valves can be manually cycled from the Control Room. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. OCONEE UNITS 1, 2, & 3 B 3.5.2-14 Rev.-893-I

BASES LPI 83.5.3 SURVEILLANCE SR 3.5.3.2 (continued) REQUIREMENTS method used for monitoring the susceptible locations and trending of the results should be sufficient to assure system OPERABILITY during the Surveillance interval. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Survemance Frequency Control Program. The Surveillance Frequency may vary by location susceptible to gas accumulation. SR 3.5.3.3 Periodic surveillance testing of LPI pumps to detect gross degradation caused by impeller structural damage or other hydraulic component bl s Is ui ASME Code (Ref. 5). SRs are specified in the the AS E Code. 0 ~ SR 3.5.3.4 end SR 3.5.3.5 These SRs demonstrate that each automatic LPI valve actuates to the required position on an actual or simulated ESPS signal and that each LPI pump starts on receipt of an actual or simulated ESPS signal. This SR is not required for valves that are locked, sealed, or otherwise secured in position under administrative controls. The test will be considered satisfactory if control board Indication veriftes that all components have responded to the ESPS actuation signal property (all appropriate ESPS actuated pump breakers have opened or closed and all ESPS actuated valves have completed their travel). The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. The actuation logic is tested as pa1rtrt~of~:=~~:;:=~~~~------ perfonnance is monitored as part Qf HSt!l\\}l:.C-'-. 'YE.ST"~"' P~flbf\\l'tt\\ SR 3.5.3.6 Periodic inspections of the reactor building sump suction inlet ensure that it is unrestricted and stays in proper operating concfrtion. The Surveillance Frequency is based on operating experience, equipment reliabffity, and plant risk and is controlled under the Surveillance Frequency Control Program. OCONEE UNlTS 1, 2, & 3 B 3.5.3-9 Rev.-ee9-I

BASES SURVEILLANCE REQUIREMENTS (continued) REFERENCES SR 3.6.3.4 Containment Isolation Valves 83.6.3 Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY. The isolation time and F uency of this SR are in accordance with tha-k~FViee.;;iMtffltft-Pn~l!ffW SR 3.6.3.5 Automatic containment isolation valves close on a containment isolation signal to prevent leakage of radioactive material from containment following an accident This SR ensures that each automatic containment isolation valve will actuate to its isolation position on a containment isolation signal. This SR is not required for valves that are locked, sealed. or otherwise secured in position under administrative controls. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

1.

UFSAR. Section 6.2.

2.

UFSAR, Section 15.14.

3.

10 CFR 50.36.

4.

UFSAR, Table6-7.

5.

Generic Letter 91-08 OCONEE UNITS 1, 2, & 3 B 3.6.3-10 B7\\GES RE¥1SIOH BATED 9S/18112 I

BASES SURVEILLANCE REQUIREMENTS (continued) SR 3.6.5.2 Reactor Building Spray and Cooling Systems B3.6.5 Operating each required reactor building cooling train fan unit for ~ 15 minutes ensures that all trains are OPERABLE and that all associated controls are functioning properly. It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.6.5.3 Verifying that each required Reactor Building Spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump perfonnance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code (Ref. 4). Since the Reactor Building Spray System pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow. This test confirms one point on the pump design curve and is Indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and may detect Incipient failures by Indicating abnormal rformance. The Frequency of this SR is in accordance with ~gfii;p;;je;~ SR 3.6.5.4 Verifying the containment heat removal capability provides assurance that the containment heat removal systems are capable of maintaining containment temperature below design limits following an accident. This test verifies the heat removal capability of the Low Pressure Injection (LPI) Coolers and Reactor Building CooHng Units. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. OCONEE UNITS 1, 2, & 3 B 3.6.5-9 Rev.--862-I

BASES APPLICABLE SAFETY ANALYSIS (continued) LCO APPLICABILITY ACTIONS The MSRVs satisfy Criterion 3 of 10 CFR 50. 36, (Ref. 5). MS RVs B 3.7.1 The MSRVs are provided to prevent overpressurization as discussed in the Appticable Safety Analysis section of these Bases. The LCO requires sixteen MSRVs. eight on each main steam line, to be OPERABLE to ensure compliance with the ASME Code following accidents and transients initiated at full power. Operation with less than a full complement of MSRVs is not permitted. To be OPERABLE, lift setpoints must remain within limits, specified in the UFSAR. The safety function of the MSRVs is to open, relieve steam generator overpressure, and reseat when pressure has been reduced. OPERABILITY of the MSRVs requires eriodic surveillance testing in accordance with th The lift settings correspond to ambient conditions of the valve at nominal operating temperature and pressure. This LCO provides assurance that the MSRVs \\Viii perform the design safety function. In MODES 1, 2, and 3, the MSRVs must be OPERABLE to prevent overpressurization of the main steam system. In MODES 4 and 5, there is no credible transient requiring the MSRVs. The steam generators are not normally used for heat removal in MODES 5 and 6, and thus cannot be overpressurized. There is no requirement for the MSRVs to be OPERABLE in these MODES. A.1 and A.2 With one or more MSRVs inoperable, the unit must be placed In a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 12 hours, and in MODE 4 within 18 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. OCONEE UNITS 1, 2, & 3 B 3.7.1-2 Rev. eez.. I

BASES (continued) MS RVs 83.7.1 SURVEILLANCE SR 3.7.1.1 REQUIREMENTS

a.

Vtsual examination;

b.

Seat tightness determination;

c.

Setpoint pressure determination (lift setting);

d.

Compliance with owner's seat tightness criteria; and

e.

Verification of the balancing device integrity on balanced valves. The ASME Code requires the testing of all valves every 5 years, with a minimum of 20% of the valves tested every 24 months. This SR is modified by a Note that states the surveillance Is only required to be performed in MODES 1 and 2. This note allows entry into and operation in MODE 3 prior to performing the SR, provided there is no evidence that the equipment is otherwise believed to be incapable of performing its function. Also. the guidance in the TS Bases for SR 3.0.1 states that equipment may be considered OPERABLE following maintenance provided testing has been satisfactorily completed to the extent possible and the equipment is not otherwise believed to be incapable of performing its function. This allows operation to proceed to a MODE or other specified condition where other necessary post maintenance tests can be completed. For example, the mode change provisions described above specifically applies to scenarios where maintenance on MSRVs is performed below the mode of applicability for LCO 3. 7.1, testing has been satisfactorily completed to the extent possible, and the equipment is believed capable of performing its function. The mode change provisions permit entry into Mode 3 in order to test and adjust the set pressure, as necessary, to satisfy SR 3. 7.1.1 prior to entry into Mode 2. The MSRVs may be either bench tested or tested in situ at hot conditions using an assist device to simulate lift pressure. If the MSRVs are not tested at hot conditions. the lift setting pressure must be corrected to ambient conditions of the valve at operating temperature and pressure. OCONEE UNITS 1, 2, & 3 B 3.7.1-3 Rev. iOd-I

BASES (continued) MFCVs and SFCVs 83.7.3 SURVEILLANCE SR 3.7.3.1 REQUIREMENTS ,,.------..:J.. REFERENCES This SR verifies that the closure time of each MFCV and SFCV is s 25 seconds on an actual or simulated actuation signal. The 25 seconds includes a 1 O second signal delay and 15 seconds for valve movement The MFCV and SFCV closure time is assumed in the containment analyses. This Surveillance is normally performed upon returning the unit to operation follo'Ning a refueling outage. The MFCV and SFCV should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. This is consistent with the ASME Code (Ref. 2) requirements during operation in MODES 1 and 2. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR. The F~uency for this SR is in accordance with the~"Festi1 !~~

1.

10 CFR 50.36.

2.

ASME Code for Operation and Maintenance of Nuclear Power Plants. OCONEE UNITS 1, 2, & 3 B 3.7.3-4 Rev.-994-I

BASES (continued) EFWSystem B 3.7.5 SURVEILLANCE SR 3.7.5.1 REQUIREMENTS Verifying the corred alignment for manual, and non-automatic power operated valves in the EFW water and steam supply flow paths provides assurance that the proper flow paths exist for EFW operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since those valves are verified to be in the correct position prior to locking, sealing, or securing. This SR also does not apply to valves that cannot be inadvertently misaligned, such as check valves. This Surveillance does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.7.5.2 Verifying that each EFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that EFW pump performance has not degraded below the acceptance criteria during the cycle. Flow and differential head are normal indications of pump performance required by the ASME Code (Ref. 3). Because it is undesirable to introduce cokl EFW into the steam generators while they are operating, this test may be performed on a test flow path. This test confirms OPERABILITY, trends performance, and detects incipient failures by indicating abnormal performance. Performance of inservice testing in the ASME Code (Ref. 3)@t 3 J?ORtb iRti~tisfies this requirement. aS> J ~r..J..S.J...e <!. SR 3.7.5.3 This SR verifies that EFW can be delivered to the appropriate steam generator in the event of any accident or transient that generates an Emergency Feedwater System initiation signal by demonstrating that each automatic valve in the flow path actuates to its correct position on an adual or simulated actuation signal. This SR is not required for valves that are locked, seated, or othecwise secured in position under administrative OCONEE UNITS 1, 2, & 3 B 3.7.5-6 Rev..Q04.. I

BASES BACKGROUND (continued) The PSW system consists of the following:

1. PSW building and associated support systems.

PSWSystem B 3.7.10

2. Conduit duct bank from the Keowee Hydroelectric Station underground cable trench to the PSW building.

3. Conduit duct bank and raceway from the PSW Building to the Unit 3 AB.

4. Electrical power distribution system from breakers at the Keowee Hydroelectric Station and from the 100 kV PSW substation (supplied from the Central Tie Switchyard) to the PSW building, and from there to the AB.

5. PSW booster pump, PSW primary pump, and mechanical piping taking suction from the Unit 2 embedded CCW System to the EFW headers supplying cooling water to the respective unit's SGs and HPI pump motor bearing coolers.

6. PSW portable pumping system.

The mechanical portion of the PSW system provides decay heat removal by feeding Lake Keowee water to the secondary side of the SGs. In addition, the PSW pumping system supplies Keowee Lake water to the HPI pump motor coolers. The PSW pumping system consists of a booster pump, a primary pump, and a portable pump. other than the portable pump, the pum.R!' and r ~ valves are eriodically tested in accordance with thellM-Se~ The PSW piping system has pump minimum flow lines that discharge back into the Unit 2 CCW embedded piping. The PSW primary and booster pumps, motor operated valves, and solenoid valves required to bring the system into service, are controlled from the main control rooms. Check valves and manual handwheel operated valves are used to prevent back-flow, accommodate testing, or are used for system isolation. The PSW electrical system is designed to provide power to PSW mechanical and electrical components as well as other system components needed to establish and maintain a safe shutdown condition. Normal power is provided by a transformer connected to a 100 kV overhead transmissi6n line that receives power from the Central Tie Switchyard located approximately eight (8) miles from the plant. Standby power is provided from the Keowee Hydroelectric Station via an underground path. The Keowee Hydro Unit (KHU) aligned to the overhead emergency power path can automatically provide power to Keowee Hydroelectric Station in-house loads for operation of the overhead KHU. OCONEE UNITS 1, 2, & 3 B 3.7.10-2 Rev. -993-I

BASES PSWSystem B 3.7.10 SURVEILLANCE SR 3.7.10.2 {continued) REQUIREMENTS Electrical intertocks prevent compromise of existing redundant emergency power paths. To verify either KHU can supply the PSW electrical system, the PSW Feeder Breaker [B6T-A] or [B7T-C and the PSW switchgear tie breaker] is closed. The Surveillance Frequency is in accordance with the Surveillance Frequency Control Program. r--~--------------~----- SR 3.7.10.3 SR 3.7.10.4 A battery service test is a special test of the battery capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length correspond to the design duty cycle requirements. The surveillance frequency is in accordance with the Surveillance Frequency Control Program. SR 3.7.10.5 This SR verifies the design capacity of the battery charger. According to Regulatory Guide 1.32 (Ref. 1 ), the battery charger supply is recommended to be based on the largest combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to the fully charged state, irrespective of the status of the unit during these demand occurrences. The minimum required amperes and duration ensure that these requirements can be satisfied. This SR provides two options. One option requires that each battery charger be capable of supplying ~300 amps for greater than 8 hours at the minimum established float voltage. The current requirements are based on the output rating of the charger. The voltage requirements are based on the charger voltage '8ve\\ aft.er a response to a loss of AC power. The time period is sufficient for the charger temperature to stabilize and to have been maintained for at least 2 hours. OCONEE UNITS 1, 2, & 3 B 3.7.10-9 Rev.Q93 I

BASES PSWSystem B 3.7.10 SURVEILLANCE SR 3.7.10.7 (continued) REQUIREMENTS Component 2HPl-SX-TRN003 (2HP-24 PSW transfer switch) 2HPl-SX-TRN004 (2HP-26 PSW transfer switch) 3HPl-SX-TRN003 (3HP-24 PSW transfer switch) 3HPl-SX-TRN004 (3HP-26 PSW transfer switch) 1PSW-SX-TRN001 (1CA CHARGER auto transfer switch) 1 PSW-SX-TRN002 (1 CB CHARGER auto transfer switch) 2PSW-SX-TRN001 (2CA CHARGER auto transfer switch) 2PSW-SX-TRN002 (2CB CHARGER auto transfer switch) 3PSW-SX-TRN001 {3CA CHARGER auto transfer switch) 3PSW-SX-TRN002 (3CB CHARGER auto transfer switch) 1PSW-SX-TRN004 (manual transfer switch for 1XJ) 1 PSW-SX-TRN005 (manual transfer switch for 1 XK) 2PSW-SX-TRN003 (manual transfer switch for 2XJ) 2PSW-SX-TRN004 {manual transfer switch for 2XI) 2PSW-SX-TRN005 {manual transfer switch for 2XK) 3PSW-SX-TRN003 (manual transfer switch for 3XJ) 3PSW-SX-TRN004 (manual transfer switch for 3XI) 3PSW-SX-TRN005 {manual trarJsfer switch for 3XK) 1 RC-155/1 RC-156 power transfer 1 RC-157 /1 RC-158 power transfer 1 RC-159/1 RC-160 power transfer 2RC-155/2RC-156 power transfer 2RC-157 /2RC-158 power transfer 2RC-159/2RC-160 power transfer 3RC-155/3RC-156 power transfer 3RC-157 /3RC-158 power transfer 3RC-159/3RC-160 power transfer The surveillance frequency is in accordance with the Surveillance Frequency Control Program. SR 3.7.10.8 SR verifies PSW booster pump and check valves can sup~er to the "A" and "B" HPI pump motor coolers in accordance with th =F ;fegii' c;;;;;vic.f" '"1f3'rtJJl:> P.tobLi0 _/ OCONEE UNITS 1, 2, & 3 B 3.7.10-11 Rev. QQ3. I

BASES SURVEILLANCE REQUIREMENTS {continued) SR 3.7.10.9 PSWSystem B 3.7.10 This SR requires that the PSW portable pump be tested to verify that the developed head of PSW portable pump at the flow test point is greater than or equal to the required developed head. The surveillance frequency is in accordance with the Surveillance Frequency Control Program. SR 3.7.10.10 Th's SR requires the required PSW valves be tested in accordance with the . The specified Frequency is in accordance with@r] ~--r-CPF!!gFelJ) requirements. SR 3.7.10.11 Performance of the CHANNEL CHECK for each required instrumentation channel ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel with a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; therefore, it is key in verifying that the instrumentation continues to operate property between each CHANNEL CALIBRATION. The instrument string to the control room is checked and calibrated periodically per the Surveillance Frequency Control Program. Agreement criteria are determined based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. If the channels are within the criteria, it is an indication that the channels are OPERABLE. If the channels are normally off scale during times when surveillance is required, the CHANNEL CHECK will only verify that they are off scale in the same direction. Off scale low current loop channels are verified to be reading at the bottom of the range and not failed downscale. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled in accordance with the Surveillance Frequency Control Program. OCONEE UNITS 1, 2, & 3 B 3.7.10-12 Rev. 8eS-I

BASES BACKGROUND (continued) SFPC Purification System Isolation from BWST B 3.7.19 The return piping from the RO unit is routed back to the purification portion of the two SFPC Purification Systems (Units 1 & 2 and Unit 3). The RO System return piping is non-seismic up to the point where connections are made to the SF purification piping. A check valve is installed in each of the return lines to the SF purification piping. The check valve and the downstream piping are seismically qualified. The location where the discharge piping connects to the purification loop is such that the return flow can be aligned to the same source supplying the RO unit. The BWST water is routed to the RO System from the SF purification loop. The two redundant automatic isolation valves are credited to isolate the RO system and the SFPC purification system to prevent unanalyzed radiological releases from either system. The valves are automatically isolated upon receipt of a low BWST level aduation signal prior to ECCS suction swapover to the reactor building sump. APPLICABLE The large break LOCA assumes back-leakage from the sump to the SAFETY ANALYSES borated water storage tank (BWST). RO system operation or BWST recirculation using the BWST recirculation pump requires a flow path to be open from the BWST. Two redundant safety related automatic isolation valves are used to isolate each SFPC Purification System (Unit 1 and 2, and Unit 3) prior to ECCS Suction swapover from the BWST to the reactor building sump to prevent unanalyzed radiological releases. With the automatic isolation of thls pathway, the use of the SFPC purification system for RO operation or BWST recirculation does not impact the assumptions in the design basis LOCA dose analysis. These automatic valve isolations are part of the primary success pathway which functions to mitigate the LOCA and meet 1 O CFR 50.36, Criterion 3 (Reference 2). The isolation of the SFPC purification system credits two safety related automatic isolation valves and several manual valves upstream of the automatic isolation valves to ensure the plant stays within the bounds of the design basis LOCA analysis. LCO This LCO requires that the two automatic isolation valves used to isolate the SFPC purification system (one set for Unit 1 & 2 and one set for Unit 3} from the BWST to be OPERABLE. The automatic isolation valves are required to close on an automatic isolation signal. The LCO requires that the SFPC Purification System branch line manual valves located u stream of the automatic valves to be and closed and meet~~ leakage requirements. OCONEE UNITS 1, 2, & 3 B 3.7.19-2 Rev.-e&t I

APPLICABILITY ACTIONS SFPC Purification System Isolation from BWST B 3.7.19 The SFPC purification system automatic isolation valves are required to be OPERABLE and t e branch line manual isolation valves are required to be closed and m leakage requirements in MODES 1, 2, 3, and 4 when the SFPC Purification System is not isolated from the BWST, consistent with emergency core cooling system (ECCS) OPERABILITY requirements. These requirements ensure the plant stays within the bounds of the design basis LOCA analysis. The ACTIONS are modified by two Notes. Note 1 allows the SFPC purification system flow path from the BWST to be unisolated intermittently under administrative controls. The opening of a closed valve in the flow path on an intermittent basis under administrative control includes the following: ( 1) stationing an operator, who is in constant communication with control room, at the valve controls, (2) instructing this operator to close these valves in an accident situation, and (3) assuring that environmental conditions will not preclude access to close the valves and that this action will prevent the release of radioactivity outside the SFPC purification system. In this way, the flow path can be rapidly isolated when a need for isolation is indicated. The maximum continuous RO system operating period is 7 days. Procedures controlling RO System operation limit operation to a specified time period to prevent the boron concentration and water level going below the TS limit of the BWST. A second Note has been added to provide clarification that, for this LCO, separate Condition entry is allowed for each branch line manual valve. This is acceptable, since the Required Actions for each applicable Condition provide appropriate compensatory actions for each inoperable manual valve. Complying with the Required Actions may allow for continued operation, and subsequent inoperable manual valves are governed by subsequent Condition entry and application of associated Required Actions. A.1 and A.2 In the event one SFPC purification system BWST automatic isolation valve is inoperable, the SFPC Purification System flow path must be isolated within 4 hours. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single adive failure. Isolation barriers that meet this criterion are a closed and de-activated automatic isolation valve, a closed and de-activated non-automatic power operated valve, a closed manual valve, or a blind flange. For the SFPC Purification System flow path isolated in accordance with Required Adion A.1, the device used to isolate the flow path should be the closest available to the inoperable SFPC Purification System BWST OCONEE UNITS 1, 2, & 3 B 3.7.19-3 Rev..e&1-I

BASES ACTIONS (continued} C.1 and C.2 SFPC System Isolation from BWST B 3.7.19 If a ~ uired manual valve(s) is discovered or not closed or not meeting@ ~llANltft'laleakage requirements. the flow path must be isolated within 1 hour. The method of isolation must include the use of at least one isolation barrier that cannot be adversely affected by a single adive failure. Isolation barriers that meet this criterion are a closed and de-adivated automatic isolation valve, a closed and de-activated non-automatic power operated valve, a closed manual valve, or a blind flange. The 1-hour Completion Time is considered reasonable, considering the time required to isolate the flow path and the low probability of an accident occurring during the time period requiring this action. This is necessary to ensure that the flow path to the top of the BWST is isolated. In the event a SFPC purification system branch line flow path is isolated in accordance with Required Action C.1, the flow path must be verified to be isolated on a periodic basis per Required Action C.2. This periodic verification is necessary to ensure that the flow path is isolated should an event occur requiring it to be isolated. The Completion Time of once per 31 days for verifying the flow path is isolated is appropriate constdering the fact that the device is operated under administrative controls and the probability of its misalignment is low. D.1 and D.2 If the Required Actions and associated Completion Times of Condition A, B, or C are not met, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 12 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderty manner and without challenging unit systems. SURVEILLANCE SR 3.7.19.1 REQUIREMENTS This SR requires verification that the SFPC Purification system branch line manual valves SF-51, 53, 54, and DW-112 for Unit 1 and 2 or 3SF-51, 53, 54, and 3DW-112 for Unit 3 that are not locked, sealed, or otherwise secured in the closed position, are closed. The SR helps to ensure that post accident leakage of radioactive fluids does not impact the offsite dose analysis. This SR does not require any testing or valve manipulation. Rather, it involves verification, through a system walkdown, OCONEE UNITS 1, 2, & 3 B 3.7.19-5 Rev. '10+ I

BASES (continued) SURVEILLANCE REQUIREMENTS (continued) REFERENCES SR 3.7.19.1 Ccontlnu15D SFPC System Isolation from BWST B 3.7.19 that each manual isolation valve Is closed. The Surveillance Frequency la based on operating experience, equipment rellablltty, and plant risk and is controlled under the Surveillance Frequency Control Program. This SR does not apply If a valve Is locked, sealed, or othelWise secured, since it was vertfied to be in the correct position upon locking, sealing, or securing. SR 3.7.19.2 SR 3.7.19.3 SR 3.7.19.4 This SR f8quiras verification that each Sf PC Pll'fflcatlon System automatic isolation valve (SF-168 and SF*167 for Unit 1 & 2 and 3SF-186 and 3SF-167 for Unit 3) actuates to the Isolation position on an actual or aimulatacl isolation algnal. Thia SR is not required for valves that are locked, sealed, or otherwise S8Ql'8d in position under administrative controls. The SR helps to ensure that post acddent leakage of radioadlve fluids do not impact the offsila dose analysis. The SuN9illance Frequency Is based on operating experience, equipment reHabBity, and plant risk and is controlled under the Survellance Frequency Control Program.

1.

UFSAR, Section 9.1.3.

2.

10 CFR 50.36. OCONEE UNITS 1. 2, & 3 B 3.7.19-6 Rev. 094-I

BASES SURVEILLANCE REQUIREMENTS (continued) SR 3.10.1.12 SSF 83.10.1 A battery service test is a special test of the battery capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length correspond to the design duty cycle requirements. The design basis discharge time for the SSF battery is one hour. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.10.1.13 CHANNEL CALIBRATION is a complete check of the instrument channel, including the sensor. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift to ensure that the instrument channel remains operational between successive tests. CHANNEL CALIBRATION shall find that measurement errors and bistable setpoint errors are within the assumptions of the setpoint analysis. CHANNEL CALIBRATIONS must be performed consistent with the assumptions of the setpoint analysis. The Surveillance Frequency is based on operating experience, equipment reliability. and plant risk and is controlled under the Surveillance Frequency Control Program. SR 3.10.1.14 lnservice Testing of the SSF valves demonstrates that the valves are mechanically OPERABLE and will operate when required. These valves are required to operate to ensure the required flow path. The specified Frequency is in accordance with e ~~flet!l1rllft'f:, (F8"1:tifiiiA;7 Operating experience has shown that these components usualJY pass the SR when performed at th r_equen. Therefore. the Frequency was concluded to be acceptable m a reliability standpoint. f N.Se1-vt e,r= tf"-STrAJG OCONEE UNITS 1, 2, & 3 B 3.10.1-16 Rev.~I

.u cJ BASES SSF 83.10.1 SURVEILLANCE SR 3.10.1.15 REQUIREMENTS (continued)

REFERENCES The specified Frequency is in accordance with the~~~~il""'" requirements. Operating experience has sho that these components usually pass the SR when performed at th i9T requency.

erefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.10.1.16 This SR requires the SSF submersible pump to be tested on a 2 year Frequency and verifies the required flow rate at a discharge pressure to verify OPERABILITY. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.

1.

UFSAR, Section 9.6.

2.

Oconee Probabilistic Risk Assessment.

3.

10 CFR 50.36.

4.

NRC Letter from L. A. Wiens to H. B. Tucker, "Safety Evaluation Report on Effect of Tomado Missiles on Oconee Emergency Feedwater System," dated July 28, 1989.

5.

NRC Letter from L. A. Wrens to J. W. Hampton, "Safety Evaluation for Station Blackout (10 CFR 50.63)- Oconee Nuclear Station. Units 1, 2, and 3," dated March 10, 1992. OCONEE UNITS 1, 2, & 3 B 3.10.1*17 Rev.-ee+-1

APPLICABILITY BASES -- 4.0.1 (Continued) 4.0.2 4.0.3 An example of this process is Auxniary Feedwater (AFW) pump turbine maintenance during refueling that requires testing at steam pressures that cannot be obtained until the unit is at HOT SHUTDOWN conditions. However, if other appropriate testing is satisfactorily completed, the AFW System can be considered OPERABLE. This allows startup and other necessary testing to proceed until the plant reaches the steam pressure required to perfonn the testing. The provisions of this specification establish the limit for which the specified time interval for Surveillance Requirements may be extended. H permits an allowable extension of the normal surveillance interva\\ to facilitate suNe\\l\\ance scheduling and consideration of plant operating conditions that may not be suitable for conducting surveiHance; e.g.* transient conditions or other ongoing surveiDance or maintenance activtties. It also provides flexibility to accommodate the length of a fuel cycle for surveillances that are perfonned at each refueling outage and are specified with an 18 month surveillance interval. It is not intended that this provision be used repeatedly as a convenience to extend surveiDance intervals beyond that specified for surveillances that are not performed during refueling outages. Likewise, it is not the intent that the 18-month interval surveillances be performed during power operation unless it is consistent with safe plant operation. The limitation of Specification 4.0.2 is based on engineering judgment and the recognition that the most probable result of any particular surveillance being performed is the verification of conformance with the Surveillance Requirements. This provision is sufficient to ensure that the reliability ensured through surveillance activities is not significantly degraded beyond that obtained from the specified surveiUance interval. Specification 4.0.3 establishes the flexibility to defer declaring affected equipment Inoperable or an affected variable outside the specified limits when a surveillance has not been completed within the specified surveHlance interval. A delay period of up to 24 hours or up to the Omit of the specified surveiUance interval, whichever is greater, applies from the point in time that it is discovered that the surveillance has not been performed in accordance with Specification 4.0.2, and not at the time that the specifled surveillance interval was not met This delay period provides adequate time to complete surveillances that have been missed. This delay period pennits the completion of a surveillance before complying with ACTrON requirements or other remedial measures that might preclude completion of the surveillance. The basis for this delay period includes consideration of unit conditions, adequate planning, availability of personnel, the time required to perform the surveillance. the safety significance of the delay in completing the required surveillance, and the recognition that the most probable result of any particulat surveillance being performed is the verification of confonnance with the requirements. SHEARON HARRIS - UNIT 1 B 314 0-2b Amendment No.~

INSERT HNP Bases 4.0.2 When a Section 6.8.4 specification states that the provisions of SR 4.0.2 are applicable, a 25% extension of the testing interval, whether stated in the specification or incorporated by reference, is permitted. The exceptions to SR 4.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply. These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS. Examples of where SR 4.0.2 does not apply are the Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the inservice testing of pumps and valves in accordance with applicable American Society of Mechanical Engineers Operation and Maintenance Code, as required by 10 CFR 50.55a. These programs establish testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot in and of themselves, extend a test interval specified in the regulations directly or by reference.

INSERT HNP Bases 4.0.3 When a Section 6.8.4 specification states that the provisions of SR 4.0.3 are applicable, it permits the flexibility to defer declaring the testing requirement not met in accordance with SR 4.0.3 when the testing has not been completed within the testing interval (including the allowance of SR 4.0.2 if invoked by the Section 6.8.4 specification).

SR Applicability B 3.0 B 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY BASES SRs ~ ~ Q._ ~ U) ~ \\J

l.

~ ~ ~ "'-~ \\) t:: '\\ ~ ~ ~ ...J) 0.. '"'"'d ~ " ~ ~ ~ <:, ~ ~ *o ~...; ~ *- ¢ s; J N - -S'" ~ 0 ~ ~- ti\\ \\l ~ ~ cl - Q._ V1 0 \\() HBRSEP Unit No. 2 SR 3.0.1 through SR 3.0.4 establish the general requirements applicable to all Specifications and apply at all times, unless otherwise stated. SR 3.0.1 establishes the requirement that SRs must be met during the MODES or other specifted conditions in the Applicability for which the requirements of the LCO apply, unless otherwise specified in the individual SRs. This Specification is to ensure that Surveillances are performed to verify the OPERABILITY of systems and components, and that variables are within specified limits. Failure to meet a Surveillance within the specified Frequency, in accordance with SR 3.0.2, constitutes a failure to meet an LCO. Systems and components are assumed to be OPERABLE when the associated SRs have been met. Nothing in this Specification, however, is to be construed as implying that systems or components are OPERABLE when:

a.

The systems or components are known to be inoperable, although still meeting the SRs; or

b.

The requirements of the Surveillance(s) are known not to be met between required Surveillance performances. Surveillances do not have to be performed when the unit is in a MODE or other specified condition for which the requirements of the associated LCO are not applicable, unless otherwise specified. The SRs associated with a test exception are only applicable when the test exception is used as an allowable exception to the requirements of a Specification. Unplanned events may satisfy the requirements (including applicable acceptance criteria) for a given SR. In this case, the unplanned event may be credited as fulfilling the performance of the SR. This allowance includes those SRs whose performance is normally precluded in a given MODE or other specified condition. (continued) B 3.0-13 Revision No.~

BASES SR 3.0.1 SR 3.0.2 HBRSEP Unit No. 2 SR Applicability B 3.0 Surveillances, including Surveillances invoked by Required (continued) Actions, do not have to be performed on inoperable equipment because the ACTIONS define the remedial measures that apply. Surveillances have to be met and performed in accordance with SR 3.0.2, prior to returning equipment to OPERABLE status. Upon completion of maintenance, appropriate post maintenance testing is required to declare equipment OPERABLE. This includes ensuring applicable Surveillances are not failed and their most recent performance is in accordance with SR 3.0.2. Post ma;ntenance testing may not be possible in the current MODE or other specified conditions in the Applicability due to the necessary unit parameters not having been established. In these situations, the equipment may be considered OPERABLE provided testing has been satisfactorily completed to the extent possible and the equipment is not otherwise believed to be incapable of performing its function. This will allow operation to proceed to a MODE or other specified condition where other necessary post maintenance tests can be completed. SR 3.0.2 establishes the requirements for meeting the specified Frequency for Surveillances and any Required Action with a Completion Time that equires the periodic performance of the Required Action on a "once per... "interval. SR 3.0.2 permits a 25% extension of the interval specified in the Frequency. This extension facilitates Surveillance scheduling and considers plant operating conditions that may not be suitable for conducting the Surveillance (e.g., transient conditions or other ongoing Surveillance or maintenance activities). (continued) B 3.0-14 Revision No:-69--

INSERT 1 RNP Bases SR 3.0.2 When a Section 5.5, "Programs and Manuals," specification states that the provisions of SR 3.0.2 are applicable, a 25% extension of the testing interval, whether stated in the specification or incorporated by reference, is permitted. INSERT 2 RNP Bases SR 3.0.2 The exceptions to SR 3.0.2 are those Surveillances for which the 25% extension of the interval specified in the Frequency does not apply. These exceptions are stated in the individual Specifications. The requirements of regulations take precedence over the TS. Examples of where SR 3.0.2 does not apply are the Containment Leakage Rate Testing Program required by 10 CFR 50, Appendix J, and the inservice testing of pumps and valves in accordance with applicable American Society of Mechanical Engineers Operation and Maintenance Code, as required by 1 O CFR 50.55a. These programs establish testing requirements and Frequencies in accordance with the requirements of regulations. The TS cannot, in and of themselves, extend a t~st interval specified in the regulations directly or by reference.

BASES SR 3.0.2 (continued) SR 3.0.3 HBRSEP Unit No. 2 SR Applicability B 3.0 The requirements of regulations ta e precedence over the TS. An example of where SR 3.0.2 does not ap

s in the a1nment Leakage Rate Testing Program. This progr e ablishes testing requirements and Frequencies in accord with the requirements of regulations.

of themselves extend a test interval specified in the As stated in SR 3.0.2, the 25% extension also does not apply to the initial portion of a periodic Completion Time that requires performance on a "once per... " basis. The 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time. One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or accomplishes the function of the inoperable equipment in an alternative manner. The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals (other than those consistent with refueling intervals) or periodic Completion Time intervals beyond those specified. SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours or up to the limit of the specified Frequency, whichever is greater, applies from the point in time that it is discovered that the Surveillance has not been performed in accordance with SR 3.0.2, and not at the time that the specified Frequency was not met. This delay period provides adequate time to complete Surveillances that have been missed. This delay period permits the completion of a Surveillance before complying with Required Actions or other remedial measures that might preclude completion of the Surveillance. The basis for this delay period includes consideration of unit conditions, adequate planning, availability of personnel, (continued) B 3.0-15 Revision No:-69-'

INSERT RNP Bases SR 3.0.3 When a Section 5.5, "Programs and Manuals," specification states that the provisions of SR 3.0.3 are applicable, it permits the flexibility to defer declaring the testing requirement not met in accordance with SR 3.0.3 when the testing has not been completed within the testing interval (including the allowance of SR 3.0.2 if invoked by the Section 5.5 specification).

BASES ACTIONS A.1 (continued) Pressurizer Safety Valves B 3.4.10 coincident with an RCS overpressure event could challenge the integrity of the pressure boundary. B.1 and B.2 If the Required Action of A. 1 cannot be met within the required Completion Time or if two or more pressurizer safety valves are inoperable, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. With any RCS cold leg temperatures at or below 3500F, overpressure protection is provided by the L TOP System. The change from MODE 1, 2, or 3 to MODE 4 reduces the RCS energy (core power and pressure), lowers the potential for large pressurizer insurges, and thereby removes the need for overpressure protection by three pressurizer safety valves. SURVEILLANCE SR 3.4.10.1 REQUIREMENT~S-------~--------- REFERENCES HBRSEP Unit No. 2 SRs are specified in e . Pressurizer safety valves are to be tested in accordance with the requirements of Section XI of the ASME Code (Ref. 4), which provides the activities and Frequencies necessary to satisfy the SRs. No additional requirements are specified.

1.

ASME, Boiler and Pressure Vessel Code, Section Ill.

2.

UFSAR. Chapter 15.

3.

WCAP-7769, Rev. 1, June 1972.

4.

ASME, Boiler and Pressure Vessel Code, Section XI. B 3.4-52 Revision No...-e--

BASES SURVEILLANCE REQUIREMENTS (continued) HBRSEP Unit No. 2 SR 3.5.2.2 ECCS - Operating 83.5.2 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths wilJ exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an actuation signal is allowed to be in a nonaccident position provided the valve will automatically reposition within the proper stroke time. This Surveillance does not require any testing or valve manipulation. Rather, it involves verification that those valves capable of being mispositioned are in the correct position. The 31 day Frequency is appropriate because the valves are operated under administrative control, and an improper valve position would only affect a single train. This Frequency has been shown to be acceptable through operating experience. SR 3.5.2.3 Periodic surveillance testing of ECCS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by Section XI of the ASME Code. This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve. This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater than or equal to the performance assumed in the plant safety analysis. This ensures that pump ance is consistent with the pump curve. SRs are specifted in th~!!!!~~~~~l!_!!!~in which encompasses Section XI of the AS

e. Section XI of the Code provides the actiVities and Frequencies necessary to satisfy the requirements.

SR 3.5.2.4 ancl SR 3.5.2.5 These Surveillances demonstrate that each automatic ECCS valve actuates to the required position on an actual or ~STIAJ& (continued) B 3.5-18 Revision No:-&-

BASES ECCS - Operating 83.5.2 SURVEILLANCE SR 3.5.2.4 and SR 3.5.2.5 (continued) REQUIREMENTS HBRSEP Unit No. 2 simulated SI signal and that each ECCS pump starts on receipt of an actual or simulated SI signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. The 18 month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for unplanned plant transients if the Surveillances were performed with the reactor at power. The 18 month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment. The actuation logic is tested as part of ESF Actuation S stem testin d uipment performance is monitored as part of ther-wltMAM!. 1&-1~lfAO SR 3.5.2.6 Periodic inspections of the containment sump suction inlet ensure that it is unrestricted and stays in proper operating condition. The 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage, on the need to have access to the location, and because of the potential for an unplanned transient if the Surveillance were performed with the reactor at power. This Frequency has been found to be sufficient to detect abnormal degradation and is confirmed by operating experience. SR 3.5.2.7 Verification of proper valve position ensures the proper flow path is established for the LHSI system following operation in RHR mode. The Frequency of 31 days is commensurate with the accessibility and radiation levels involved in performing the surveillance (Ref. 6). SR 3.5.2.8 Verification of proper valve position ensures the proper flow path is established for the LHSI system following operation in RHR mode. The Frequency of 92 days is based on (continued) B 3.5-19 Revision No."'6-

BASES LCO APPLICABILITY ACTIONS HBRSEP Unit No. 2 Containment Isolation Valves B3.6.3 Containment isolation valves form a part of the containment boundary. The containment isolation valves' safety function is related to minimizing the loss of reactor coolant inventory and establishing the containment boundary during a OBA. The automatic power operated isolation valves are required to have isolation times within limits and to actuate on an automatic isolation signal. The inboard 42 inch purge valves must have blocks installed to prevent full opening and actuate closed on an automatic signal. The valves cover~ b this LCO are listed along with their associated stroke times in thtllf'6a~~iilii:ii~*iiW he normally closed isolation valves are considered OPERABLE when manual valves are closed, automatic valves are de-activated and secured in their closed position, or blind flanges are in place. This LCO provides assurance that the containment isolation valves and purge valves will perform their designed safety functions to minimize the loss of reactor coolant inventory and establish the containment boundary during accidents. In MODES 1, 2, 3, and 4, a OBA could cause a release of radioactive material to containment. In MODES 5 and 6, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, the containment isolation valves are not required to be OPERABLE in MODE 5. The requirements for containment isolation valves during MODE 6 are addressed in LCO 3.9.4, "Containment Penetrations." The ACTIONS are modified by a Note allowing penetration flow paths, to be unisolated intermittently under administrative controls. These administrative controls consist of stationing a dedicated operator at the valve controls, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for containment isolation is indicated. (continued) B 3.6-16 Revision No...+t--

BASES Containment Isolation Valves B3.6.3 SURVEILLANCE SR 3.6.3.3 (continued) REQUIREMENTS HBRSEP Unit No. 2 administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3, and 4. for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in their proper position, is small. SR 3.6.3.4 Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY. The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analyses. The isolation ti F uen of this SR are i a ance with the nservice Testing (IST) Program. In addition tot testing frequency, the 42 inch purge supply and exhaust valves will be tested prior to use if not tested within the previous quarter. Otherwise, the 42 inch purge supply and exhaust valves are not cycled quarterly only for testing purposes. SR 3.6.3.5 Automatic containment isolation valves close on a containment isolation signal to prevent leakage of radioactive material from containment following a OBA. This SR ensures that each automatic containment isolation valve will actuate to its isolation position on a containment isolation signal. This surveillance is not required for valves that are tocked, sealed, or otherwise secured in the required position under administrative controls. The 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these oomponents usually pass this Surveillance when performed at the 18 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. (continued) B 3.6-24 Revision No.~

BASES Containment Spray and Cooling Systems B 3.6.6 SURVEILLANCE SR 3.6.6.3 (continued) REQUIREMENTS HBRSEP Unit No. 2 train redundancy available, and the low probability of a significant degradation of flow occurring between surveillances. SR 3.6.6.4 Verifying each containment spray pump's developed head at the flow test point Is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by Section XI of the ASME Code {Ref. 5). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow. This test confirms pump performance is consistent with the pump design curve and is indicative of overall performance, by setting the pump head and measuring the test flow. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by Indicating abnormal P.';~~aiin~ce~. ~Thie~F ~u~e~n.cy of the SR is in accordance with th : 11 SR 3.6.6.5 and SR 3.6.6.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated actuation of a containment High - High pressure signal. SR 3.6.6.5 is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. SR 3.6.6.6 must be performed with the isolation valves in the spray supply lines at the containment and spray additive tank locked closed. The 18 month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillances when performed at the 18 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint (continued) B 3.641 Revision No.+-

BASES ACTIONS (continued) B.1 and B.2 IVSWSystem B 3.6.8 If the Required Actions and associated Completion Times are not met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at feast MOOE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Compfetion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging pf ant systems. SURVEILLANCE SR 3.6.8.1 REQUIREMENTS HBRSEP Unit No. 2 This SR verifies the IVSW tank has the necessary pressure to provide motive force to the seal water. A pressure ce 46.2 psig ensures the containment penetration flowpaths that are sealed by the IVSW System are maintained at a pressure which is at least 1.1 times the calculated peak containment internal pressure (Pa) related to the design bases accident. Verification of the IVSW tank pressure on a Frequency of once per 12 hours is acceptable. This Frequency Is sufficient to ensure availability of IVSW. Operating experience has shown this Frequency to be appropriate for early detection and correction of off normal trends. SR 3.6.8.2 This SR verifies the IVSW tank has an initial volume of water necessary to provide seal water to the containment isolation valves served by the IVSW System. An initial volume ~ 85 gallons ensures the IVSW System contains the proper inventory to maintain the required seal. Verification of IVSW tank level on a Frequency of once per 31 days is acceptable since tank level is continuously monitored by installed instrumentation and will alarm in the control room prior to level decreasing to 85 gallons. SR 3.6.8.3 This SR verifies the stroke time of each automatic air operated header il')jection solenoid valve is within limits. The frequency is specified by the!!!.r!!Ci Tiit1"g ) (continued) B 3.6-52 Revision No.- BASES IVSWSystem 83.6.8 SURVEILLANCE SR 3.6.8.3 (continued) REQUIREMENTS ~ and previous operating experience has shown that these valves ~p&ss the required test when performed. SR 3.6.8.4 This SR ensures that automatic header injection valves actuate to the correct position on a simulated or actual signal. The 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 18 month Frequency. Therefore, the Frequency was concluded to be acceptable. SR 3.6.8.5 This SR ensures the capability of the dedicated nitrogen bottles to pressurize the IVSW system independent of the Plant Nitrogen System. The 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. SR 3.6.8.6 Integrity of the IVSW seal boundary is important in providing assurance that the design leakage value required for the system to perform its sealing function is not exceeded. The 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. (continued) HBRSEP Unit No. 2 B 3.6-53 Revision No.-e--

BASES MSSVs 83.7.1 APPLICABLE event occurring from a partial power level may result in an SAFETY ANALYSES increase in reactor power that exceeds the combined steam (continued) flow capacity of the turbine and the remaining OPERABLE MSSVs. LCO APPLICABILITY HBRSEP Unit No. 2 Thus, for multiple inoperable MSSVs on the same steam generator it is necessary to prevent this power increase by lowering the Power Range Neutron Flux-High setpoint to an appropriate value. When the Moderator Temperature Coefficient (MTC) is positive, the reactor power may increase above the initial value during an RCS heatup event (e.g., turbine trip}. Thus, for any number of inoperable MSSVs it is necessary to reduce the trip setpoint if a positive MTC may exist at partial power conditions. The MSSVs satisfy Criterion 3 of the NRC Policy Statement. The accident analysis assumes four MSSVs per steam generator are OPERABLE to provide overpressure protection for design basis transients occurring at 102% of the pre-Appendix K power uprate licensed power level of 2300 MWt (i.e., 2346 MWt). The LCO, therefore, also requires that four MSSVs per steam generator be OPERABLE. The OPERABILITY of the MSSVs is defined as the ability to open upon demand within the setpoint tolerances, relieve steam generator overpressure, and reseat when pressure has been reduced. The OPERABILITY of the MSSVs is. determined b~~odic surveillance testing in accordance with th~service TestH1 ffiiRii9J This LCO provides assurance that the MSSVs will perform their designed safety functions to mitigate the consequences of accidents that could result in a challenge to the RCPB, or Main Steam System integrity. In MODES 1, 2, and 3, four MSSVs per steam generator are required to be OPERABLE to prevent Main Steam System overpressurization. In MODES 4 and 5, there are no credible transients requiring the MSSVs. The steam generators are not normally used for heat removal in MODES 5 and 6, and thus cannot be overpressurized; there is no requirement for the MSSVs to be OPERABLE in these MODES. (continued) 83.7-3 Revision No.- BASES (continued) MSSVs 83.7.1 SURVEILLANCE SR 3. 7.1.1 REQUIREMENTS This SR verifies the OPERABILITY of the MSSVs by the verification of each MSSV lift set int in accordance with th . The ASME e, e on ef. 5), requires that safety and ti'7'~-re-,...-e... va-lve tests be performed in accordance with ASME OM Code REFERENCES HBRSEP Unit No. 2 (Ref. 6}. According to Reference 6, the following tests are required:

a.

Visual examination;

b.

Seat tightness determination:

c.

Setpoint pressure determination (lift setting);

d.

Compliance with owner-s seat tightness criteria; and The ASME OM Code requires that all valves be tested every 5 years, and a minimum of 20% of the valves be tested every 24 months. The ASME Code specifies the activities and frequencies necessary to satisfy the requirements. Table 3. 7.1-2 allows a :t 3% setpoint tolerance for OPERABILITY; however, the valves are reset to :t 1 % during the Surveillance to allow for drift. The lift settings, according to Table 3.7.1-2, correspond to ambient conditions of the valve at nominal operating temperature and pressure. This SR is modified by a Note that allows entry into and operation in MOOE 3 prior to performing the SR. The MSSVs may be either bench tested or tested in situ at hot conditions using an assist device to simulate lift pressure. If the MSSVs are not tested at hot conditions, the lift setting pressure shall be corrected to ambient conditions of the valve at operating temperature and pressure.

1.

UFSAR, Section 10.3.2.

2.

ASME, Boiler and Pressure Vessel Code, Section Ill.

3.

UFSAR, Section 15.2. (continued) B 3.7-6 Revision No. BASES SURVEILLANCE REQUIREMENTS (continued) REFERENCES HBRSEP Unit No. 2 SR 3.7.2.1 (continued) MS I Vs B 3.7.2 containment analyses with the exception of closure of the MSIVs for a MSLB at 100% RTP, in which case MSIV closure in 2 seconds is assumed for MSIVs which ctose in the forward flow direction. The MSIVs should not be tested at power, since even a part stroke exercise Increases the risk of a valve closure when the unit is generating power. As the MSIVs are not tested at power, they are exempt from the ASME Code, Section XI (Ref. 5), requirements during operation in MODE 1 or 2. The Frequency is in accordance with th . The specified Frequency for valve closure time is on re mg cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the specified Frequency. Therefore, the Frequency is acceptable from a reliability standpoint This test is conducted in MODE 3 with the unit at operating temperature and pressure, as discussed in Reference 5 exercising requirements. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR. This allows a delay of testing until MODE 3, to establish conditions consistent with those under which the acceptance criterion was generated.

1.

UFSAR, Section 10.3.

2.

UFSAR, Section 6.2.

3.

UFSAR, Section 15.1.5.

4.

TRM, Section 4.0

5.

ASME, Boiler and Pressure Vessel Code, Section XI. B 3.7-13 Revision No..es-

BASES (continued) MFIVs, MFRVs, and Bypass Valves 83.7.3 SURVEILLANCE SR 3.7.3.1 REQUIREMENTS HBRSEP Unit No. 2 This SR verifies that the closure time of each MFRV and bypass valve is within limits (Ref. 4) on an actual or simulated actuation signal. The MFRV, and bypass valve closure times are assumed in the accident and containment analyses (Ref. 2). This Surveillance is normally performed upon returning the unit to operation following a refueling outage. These valves should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. This is consistent with the ASME Code, Section XI (Ref. 3). SR 3.7.3.2 This SR verifies that the closure time of each MFIV is within limits (Ref. 4} on an actual or simulated actuation signal. The MFIV closure times are assumed in the accident and containment analyses (Ref. 2). This Surveillance is normally performed upon returning the unit to operation following a refueling outage. These valves should not be tested at power since even a part stroke exercise increases the risk of a valve closure with the unit generating power. This is consistent with the ASME Code, Section XI (Ref. 3). (continued) B 3.7-19 Revision No. -es-}}

v t e Letter Sequence Request
EPID:L-2017-LLA-0377, TSTF-545 (Approved, Closed)
Initiation Request Acceptance Administration Questions Answers Results Approval Other:
MONTHYEAR2017-12-07 [Table View]

RA-17-0005, Application to Revise Technical Specifications to Adopt TSTF-545, Revision 3, TS Inservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing

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RA-17-0005, Application to Revise Technical Specifications to Adopt TSTF-545, Revision 3, TS Inservice Testing Program Removal & Clarify SR Usage Rule Application to Section 5.5 Testing

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