Text

Application to Revise Technical Specifications to Adopt TSTF-523, Revision 2, Generic Letter 2008-01, Managing Gas Accumulation, Using the Consolidated Line Item Improvement Process
	ML14330A247
Person / Time
Site:	Wolf Creek
Issue date:	11/20/2014
From:	Mccoy J; Wolf Creek
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	ET 14-0034
	Download: ML14330A247 (90)
	v • d • e

VMLFCREEK NUCLEAR OPERATING CORPORATION Jaime H. McCoy Vice President Engineering November 20, 2014 ET 14-0034 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555

Reference:

Letter ET 08-0045, dated October 10, 2008, from T. J. Garrett, WCNOC, to USNRC

Subject:

Docket No. 50-482: Application to Revise Technical Specifications to Adopt TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," Using the Consolidated Line Item Improvement Process Gentlemen:

Pursuant to 10 CFR 50.90, "Application for amendment of license, construction permit, or early site permit," Wolf Creek Nuclear Operating Corporation (WCNOC) hereby requests an amendment to Renewed Facility Operating License No. NPF-42 for the Wolf Creek Generating Station (WCGS). The proposed amendment would modify the WCGS Technical Specifications (TS) requirements to address Nuclear Regulatory Commission (NRC) Generic Letter 2008-01, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems," as described in Technical Specification Task Force (TSTF)

Traveler TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation." In the Reference, WCNOC committed to monitor the industry resolution of the gas accumulation TS issues and submit a license amendment request, as appropriate, within one year following NRC approval of the TSTF or the Consolidated Line Item Improvement Process (CLIIP) Notice of Availability.

Attachment I provides a description of the proposed change and the supporting assessment of applicability and plant-specific variations. Attachment II provides the existing TS pages marked up to show the proposed change. Attachment III provides revised (clean) TS pages.

Attachment IV provides the existing TS Bases pages marked up to show the proposed changes and is for information only. Final TS Bases changes will be implemented pursuant to TS 5.5.14, "Technical Specification (TS) Bases Control Program," at the time the amendment is implemented.

P.O. Box 411 / Burlington, KS 66839 / Phone: (620) 364-8831 An Equal Opportunity Employer M/F/HCNET

ET 14-0034 Page 2 of 3 It has been determined that this amendment application does not involve a significant hazard consideration as determined per 10 CFR 50.92, "Issuance of amendment." Pursuant to 10 CFR 51.22, "Criterion for categorical exclusion; identification of licensing and regulatory actions eligible for categorical exclusion or otherwise not requiring environmental review," Section (b),

no environmental impact statement or environmental assessment needs to be prepared in connection with the issuance of this amendment.

The Plant Safety Review Committee reviewed this amendment application. In accordance with 10 CFR 50.91, "Notice for public comment; State consultation," a copy of this amendment application, with attachments, is being provided to the designated Kansas State official.

WCNOC requests approval of the proposed amendment prior to November 2, 2015. It is anticipated that the license amendment, as approved, will be effective upon issuance and will be implemented within 90 days of NRC issuance.

This letter contains no commitments. If you have any questions concerning this matter, please contact me at (620) 364-8460, or Mr. Steven R. Koenig at (620) 364-4041.

Sincerely, Jamie H. McCoy JHM/rlt Attachments: I Description and Assessment II Proposed Technical Specification Changes (Markup)

III Revised Technical Specification Pages IV Proposed Technical Specification Bases Changes (For Information Only) cc: T. A. Conley (KDHE), w/a M. L. Dapas (NRC), w/a C. F. Lyon (NRC), w/a N. F. O'Keefe (NRC), w/a Senior Resident Inspector (NRC), w/a

ET 14-0034 Page 3 of 3 STATE OF KANSAS )

COUNTY OF COFFEY )

Jamie H. McCoy, of lawful age, being first duly sworn upon oath says that he is Vice President Engineering of Wolf Creek Nuclear Operating Corporation; that he has read the foregoing document and knows the contents thereof; that he has executed the same for and on behalf of said Corporation with full power and authority to do so; and that the facts therein stated are true and correct to the best of his knowledge, information and belief.

By_ &4-mt %

Jamie H/McCoy Vice President Engineering SUBSCRIBED and sworn to before me this 2Oe-z day of /L/Ollen Le( , 2014.

xNotary pir lic Expiration Date /o/

Attachment I to ET 14-0034 Page 1 of 9 DESCRIPTION AND ASSESSMENT

1.0 DESCRIPTION

2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation 2.2 Optional Changes and Variations

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration 4.0 ENVIRONMENTAL EVALUATION

5.0 REFERENCES

Attachment I to ET 14-0034 Page 2 of 9 DESCRIPTION AND ASSESSMENT

1.0 DESCRIPTION

The proposed change revises or adds Surveillance Requirements to verify that the system locations susceptible to gas accumulation are sufficiently filled with water and to provide allowances which permit performance of the verification. The changes are being made to address the concerns discussed in Generic Letter 2008-01, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems," (Reference 1). In Reference 2, WCNOC committed to monitor the industry resolution of the gas accumulation technical specification (TS) issues and submit a license amendment request, as appropriate, within one year following NRC approval of the Technical Specification Task Force (TSTF) traveler or the Consolidated Line Item Improvement Process (CLIIP) Notice of Availability.

The proposed amendment is consistent with TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," (Reference 3) with variations as discussed in Section 2.2 below.

2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation Wolf Creek Nuclear Operating Corporation (WCNOC) has reviewed the model safety evaluation dated January 15, 2014 as part of the Federal Register Notice of Availability, "TSTF-523, "Generic Letter 2008-01, Managing Gas Accumulation," Using the Consolidated Line Item Improvement Process," (Reference 4). This review included a review of the NRC staff's evaluation, as well as the information provided in TSTF-523, Revision 2. As described in the subsequent paragraphs, WCNOC has concluded that the justifications presented in the TSTF-523 proposal and the model safety evaluation prepared by the NRC staff are applicable to the Wolf Creek Generating Station (VVCGS) and justify this amendment for the incorporation of the changes to the WCGS Technical Specifications.

2.2 Optional Changes and Variations The WCGS TS utilize different numbering than the Standard Technical Specifications on which TSTF-523, Revision 2, was based. Specifically, TSTF-523 adds new Surveillance Requirement (SR) SR 3.6.6A.4 to TS 3.6.6A, "Containment Spray and Cooling Systems (Atmospheric and Dual)," and renumbers the remaining SRs, whereas WCNOC is proposing to add SR 3.6.6.9 to TS 3.6.6, "Containment Spray and Cooling Systems," and not renumber existing SRs. The insertion of new SR 3.4.6.4 and SR 3.6.6.9 results in the renumbering of pages in Section 3.4 and Section 3.6 which results in a change to page ii of the Table of Contents. These differences are administrative and do not affect the applicability of TSTF-523 to the WCGS TS.

WCNOC is proposing variations from the TS changes described in TSTF-523, Revision 2, and the applicable parts of the NRC staffs model safety evaluation dated January 15, 2014.

Specifically, WCNOC is proposing a Frequency of 92 days for SR 3.5.2.3 and SR 3.6.6.9 in lieu of the specified 31 day Frequency. The justification for the extended Frequency is provided below.

Attachment I to ET 14-0034 Page 3 of 9 TS 3.5.2, "ECCS - Operating," SR 3.5.2.3 The Emergency Core Cooling System (ECCS) is verified to be sufficiently filled with water in accordance with Surveillance procedures STS BG-007A, "ECCS Valve Check and Train A &

Common Void Monitoring and Venting," and STS BG-007B, "ECCS Train B Void Monitoring and Venting." These procedures are required to be performed once per 31 days during MODES 1, 2, or 3 to satisfy the requirements of SR 3.5.2.3. Extensive WCGS operating history is available regarding the rate at which gas accumulation is identified. An evaluation of the plant operating history determined that a Surveillance Frequency of 92 days would not adversely impact the ability of the ECCS to perform its specified safety function.

There are currently a total of 112 locations which are monitored for gas accumulation (voids) every 31 days by performance of procedures STS BG-007A/B. This includes 12 locations in containment, which are monitored monthly or an alternative method of monitoring is performed if the calculated stay time is less than 60 minutes and no void factors are present (e.g., ECCS system depressurizations, accumulator leakage, etc.). The total number of locations monitored during each of the last four operating cycles is listed below. The total number of locations monitored also include those performed using procedures STS BG-002A, "Train A ECCS System Vent for Mode 4," and STS BG-002B, "Train B ECCS System Vent for Mode 4." These procedures are required to be performed once per 31 days during MODE 4 to satisfy the requirements of SR 3.5.3.1. SR 3.5.3.1 specifies that SR 3.5.3.2 is applicable for the equipment required to be OPERABLE.

Starting Date Total Number of Cycle 1 for Trending Locations Monitored 20 3/18/2013 2,250 (through 8/5/2014) 19 4/16/2011 2,618 18 11/14/2009 2,195 17 5/5/2008 1,501 1 For the purposes of this license amendment request, the cycle is typically from the transition out of a defueled condition until transition into a defueled condition at the next refueling outage.

Pertinent results from gas accumulation monitoring are discussed as follows:

Cycle 20: No voids have been detected during Cycle 20 through August 5, 2014 (MODE 1 through MODE 5). Only one void was detected while the plant was in MODE 6 during Refueling Outage 19. This void was detected during monitoring for gas accumulation after system restoration.

Cycle 19: Eight voids were detected during Cycle 19. Six of these voids were at the same location in the discharge piping of residual heat removal (RHR) Train 'B' piping to the 'D' accumulator injection line (at valve EJV0088). Two of the six voids detected at EJV0088 were larger than the then-current acceptance criteria. An evaluation of the void detected on March 26, 2012, determined that the void had formed shortly after entry into MODE 3 (from MODE 4) and that the void was present for approximately 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months before being vented. For the void detected on July 24, 2014, with the plant in MODE 1, the exact size of the void could not be determined resulting in estimating a conservative

Attachment I to ET 14-0034 Page 4 of 9 void size. An evaluation of the estimated void size determined that the RHR System was still capable of performing its specified safety function.

The voids found at EJV0088 during Cycle 19 were a result of Reactor Coolant System (RCS) and/or accumulator leakage back into the discharge piping of the RHR System through second-off check valve EP8818D. As a result of leakage from the RCS, a total of 15 first-off and second-off ECCS check valves were inspected, reworked, or replaced during Refueling Outage 19 (Spring 2013). As a result of this extensive check valve repair/replacement campaign conducted during Refueling Outage 19, RCS/accumulator leakage into the ECCS has significantly improved during the current operating cycle (Cycle 20), with no pressurization of the discharge portion of ECCS piping having been observed.

Two other voids were detected during Cycle 19 which were located in the Safety Injection System. Both voids were much smaller than the acceptance criteria, and were not detected during any follow-up testing.

Cycle 18: Voiding detected during Cycle 18 was primarily the result of accumulator leakage into the RHR System (which was detected at EJV0088), or was a result of the large void detected in the 'A' RHR heat exchanger. These conditions were addressed by repair/replacement of the ECCS check valves (as discussed above) and ensuring that the RHR heat exchangers are properly dynamically vented. A small number of other voids were detected which were much smaller than the acceptance criteria, and were not detected during follow-up testing.

" Cycle 17: No voids were detected during Cycle 17 which were larger than the acceptance criteria. No voids were detected at after the first 40 days after Refueling Outage 16 (Spring 2008) until after Refueling Outage 17 (Fall 2009, part of Cycle 18).

In summary, no gas accumulation (voids) has been detected in the ECCS since the beginning of Cycle 17 (May 5, 2008) which were determined to impact the ability the ECCS to perform its specified safety function. In addition, the two most significant causes of voiding in the ECCS (RCS/accumulator leakage into the ECCS and inadequate fill and vent of the RHR heat exchangers) have been addressed via an extensive check valve repair/replacement campaign conducted during Refuel Outage 19 and proper performance of a dynamic fill and vent of the RHR System.

Voids remaining in the ECCS as a result of inadequate system fill and vent are addressed in the following manner. Prior to entry into MODE 4, procedures STS BG-002A/B are performed to ensure that one train of ECCS is OPERABLE. Prior to entry into MODE 3 procedures STS BG-007A/B are performed to ensure that both trains of ECCS are OPERABLE. If any portion of the ECCS piping, pumps, or valves is partially or completely drained for maintenance, Engineering develops a system restoration plan that includes both a strategy for fill and vent of the drained portion of the system and a determination of what susceptible locations to be monitored will be required after the fill and vent is complete. These actions provide adequate confidence that gas accumulation from an inadequate system fill and vent will not challenge ECCS OPERABILITY.

Potential leakage from the accumulators into the ECCS is continuously monitored from the plant computer system. If any of the four accumulator levels change (decrease or increase) by more than 0.04% in a one-hour period, an electronic mail alert is sent to the System Engineer and to the Senior Reactor Operators (SROs), including the Shift Managers. This ensures that the operating crew is notified of the level change in the event that the System Engineer is not on

Attachment I to ET 14-0034 Page 5 of 9 site. The System Engineer and/or SROs will initiate a trend evaluation of the accumulator level to determine if the level change is indicative of leakage into or out of the accumulators. Actions will then be taken to address the condition, including initiation of a condition report, requesting monitoring of susceptible locations in the ECCS. Monitoring of the level of the accumulators and notifying the System Engineer and SROs of large level changes provides adequate confidence that appropriate actions are initiated and completed prior to the accumulation of a volume of gas from accumulator leakage that could challenge ECCS OPERABILITY.

Operating Experience (OE) from Joseph M. Farley Nuclear Plant, Units 1 and 2, shows that pressure decreases in the Volume Control Tank (VCT) can cause gas bubble formation in the suction piping to the centrifugal charging pumps (CCPs), which could potentially render the ECCS inoperable. Based on a review of the OE, it was determined that if the VCT pressure decreases more than 10 psi during MODES 1-4 (the TS modes of applicability for the ECCS),

confirmatory void monitoring should be performed at four locations in the CCP suction piping.

This void monitoring should be performed within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the time of the pressure decrease. Monitoring of the VCT pressure is performed in procedure CKL ZL-003, "Control Room Daily Readings," and requires that ifthe VCT pressure has dropped by more than 10 psig in the past seven days, a condition report is initiated to perform the monitoring for voids.

Monitoring of the VCT pressure provides adequate confidence that void monitoring is initiated and completed prior to the accumulation of a volume of gas that could challenge ECCS OPERABILITY.

Given that no gas accumulation which would prevent the ECCS from performing its specified safety function has been detected based on the monitoring of 8,564 locations from the beginning of Cycle 17 (May 2008) through August 5, 2014, and the measures taken to monitor gas intrusion precursors, a Surveillance Frequency of 92 days for SR 3.5.2.3 is considered to provide reasonable assurance that the ECCS is sufficiently filled with water.

TS 3.6.6, "Containment Spray and Cooling Systems," New SR 3.6.6.9 The proposed new SR 3.6.6.9 for the Containment Spray System requires that containment spray locations susceptible to gas accumulation are sufficiently filled with water. The Surveillance Frequency as proposed in TSTF-523, Revision 2, is 31 days.

The Containment Spray System is verified to be sufficiently filled with water in accordance with procedures STN EN-003A, "Containment Spray Train A & Common Void Monitoring and Venting," and STN EN-003B, "Containment Spray Train B Void Monitoring and Venting." These procedures can be performed as often as directed by Engineering, with no required Frequency.

Historically, these procedures were performed monthly during Cycle 17 and the first portion of Cycle 18. Since January 2010, these procedures have been performed quarterly (approximately every 92 days) throughout the remainder of Cycle 18 and all of Cycle 19 and Cycle 20. An evaluation of the plant operating history determined that a Surveillance Frequency of 92 days would not adversely impact the ability of the Containment Spray System to perform its specified safety function.

Attachment I to ET 14-0034 Page 6 of 9 There are currently a total of 11 locations which are monitored for gas accumulation (voids) every 92 days by performance of procedures STN EN-003A/B. The total number of locations tested during each of the last four operating cycles is listed below.

Starting Date Total Number of Cycle 1 for Trending Locations Monitored 20 3/11/2013 78 (through 8/5/2014) 19 4/21/2011 166 18 10/28/2009 136 17 6/5/2008 179 1 For the purposes of this license amendment request, the cycle is typically from the transition out of a defueled condition until transition into a defueled condition at the next refueling outage.

Pertinent results from gas accumulation monitoring are discussed as follows:

" Cycle 20: No voids have been detected during Cycle 20 through August 5, 2014 (MODE 1 through MODE 5). Only one void was detected while the plant was in MODE 6 during Refueling Outage 19. This void was detected during monitoring for gas accumulation after system restoration.

" Cycle 19: Two voids were detected during Cycle 19 with the plant operating in MODE 1.

Both voids were located in the Train 'B' suction piping at the containment recirculation sump isolation valve. The first void was larger than the then-current acceptance criteria.

Further evaluation determined that the as-found size of the void did not impact the ability of the Containment Spray System to perform its specified safety function.

Cycle 18: Three voids were detected during Cycle 18 with the plant operating in MODE

1. Two of the voids were located in the spray additive tank discharge piping to the Train

'A' containment spray pump suction. Both of these voids were much smaller than the acceptance criteria. The third void was located in the Train 'A' suction piping at the containment recirculation sump isolation valve and was larger than the then-current acceptance criteria. Further evaluation determined that the as-found size of this void did not impact the ability of the Containment Spray System to perform its specified safety function.

Cycle 17: A single void was detected during Cycle 17. This void was located in the Train 'A' suction piping at the containment recirculation sump isolation valve, and was smaller than the then-current acceptance criteria.

Given that no gas accumulation which would prevent the Containment Spray System from performing its specified safety function has been detected based on the monitoring of 559 locations from the beginning of Cycle 17 (June 2005) through August 5, 2014, a Surveillance Frequency of 92 days for new SR 3.6.6.9 is considered to provide reasonable assurance that the Containment Spray System is sufficiently filled with water.

Attachment I to ET 14-0034 Page 7 of 9

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Determination Wolf Creek Nuclear Operating Corporation (WCNOC) requests adoption of Technical Specification Task Force (TSTF) traveler TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," which is an approved change to the standard technical specifications (STS), into the Wolf Creek Generating Station (WCGS) technical specifications (TS). The proposed change revises or adds Surveillance Requirements to verify that the system locations susceptible to gas accumulation are sufficiently filled with water and to provide allowances which permit performance of the verification. WCNOC is proposing variations from the TS changes described in TSTF-523, Revision 2, and the applicable parts of the NRC staff's model safety evaluation dated January 15, 2014. Specifically, WCNOC is proposing a Frequency of 92 days for Surveillance Requirements (SR) SR 3.5.2.3 and SR 3.6.6.9 in lieu of the specified 31 day Frequency.

WCNOC 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 or adds SRs that require verification that the Emergency Core Cooling System (ECCS), the Residual Heat Removal (RHR) System, and the Containment Spray System are not rendered inoperable due to accumulated gas and to provide allowances which permit performance of the revised verification. Gas accumulation in the subject systems is not an initiator of any accident previously evaluated. As a result, the probability of any accident previously evaluated is not significantly increased. The proposed SRs ensure that the subject systems continue to be capable to perform their assumed safety function and are not rendered inoperable due to gas accumulation. Thus, the consequences of any accident previously evaluated are not significantly increased.

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 revises or adds SRs that require verification that the ECCS, the RHR System, and the Containment Spray System are not rendered inoperable due to accumulated gas and to provide allowances which permit performance of the revised verification. The proposed change does not involve a physical alteration of the plant (i.e.,

no new or different type of equipment will be installed) or a change in the methods governing normal plant operation. In addition, the proposed change does not impose any new or different requirements that could initiate an accident. The proposed change does

Attachment I to ET 14-0034 Page 8 of 9 not alter assumptions made in the safety analysis and is consistent with the safety analysis assumptions.

Therefore, the proposed change does not create the possibility of a new or different kind of accident from any accident previously evaluated.

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

Response: No.

The proposed change revises or adds SRs that require verification that the ECCS, the RHR System, and the Containment Spray System are not rendered inoperable due to accumulated gas and to provide allowances which permit performance of the revised verification. The proposed change adds new requirements to manage gas accumulation in order to ensure the subject systems are capable of performing their assumed safety functions. The proposed SRs are more comprehensive than the current SRs and will ensure that the assumptions of the safety analysis are protected. The proposed change does not adversely affect any current plant safety margins or the reliability of the equipment assumed in the safety analysis. Therefore, there are no changes being made to any safety analysis assumptions, safety limits or limiting safety system settings that would adversely affect plant safety as a result of the proposed change.

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

Based on the above, WCNOC 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.

3.2 Conclusions In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

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 a significant increase in the amounts of any effluent that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

Attachment I to ET 14-0034 Page 9 of 9

5.0 REFERENCES

1. Generic Letter (GL) 2008-01, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems," January 11, 2008. ADAMS Accession No. ML072910759

2. WCNOC Letter ET 08-0045, "Nine-Month Response to NRC Generic Letter 2008-01, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems"," October 10, 2008. ADAMS Accession No. ML082950487.

3. Technical Specifications Task Force Traveler (TSTF) TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," February 21, 2013. ADAMS Accession No. ML13053A075

4. Federal Register Notice of Availability (79 FR 2700), "TSTF-523, "Generic Letter 2008-01 Managing Gas Accumulation," Using the Consolidated Line Item Improvement Process,"

January 15, 2014.

Attachment II to ET 14-0034 Page 1 of 11 ATTACHMENT II PROPOSED TECHNICAL SPECIFICATION CHANGES (MARKUP)

Attachment IIto ET 14-0034 Page 2 of 11 RCS Loops - MODE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 ----- NOTE---

Only required if one RHR loop is OPERABLE.

Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. Required loops inoperable. B.1 Suspend operations that Immediately would cause introduction OR into the RCS, coolant with boron concentration less No RCS or RHR loop in than required to meet operation. SDM of LCO 3.1.1.

AND B.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.2 Verify SG secondary side narrow range water levels 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months are __6% for required RCS loops.

SR 3.4.6.3 Verify correct breaker alignment and indicated power 7 days are available to the required pump that is not in operation.

Wolf Ce3.4-13 Wolf Creek - Unit 1 3.4-13 Amendment No. Q2-,446-

Attachment II to ET 14-0034 Page 3 of 11 INSERT 3.4-13 SR 3.4.6.4 ------------------ NOTE ------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4.

Verify required RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

Attachment II to ET 14-0034 Page 4 of 11 RCS Loops-MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.7.2 Verify SG secondary side wide range water level is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

> 66% in required SGs.

SR 3.4.7.3 Verify correct breaker alignment and indicated power 7 days are available to the required RHR pump that is not in operation.

Wolf Creek - Unit 1 3.4-16 Amendment No. 423-

Attachment II to ET 14-0034 Page 5 of 11 RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend operations that Immediately inoperable, would cause introduction into the RCS, coolant with OR boron concentration less than required to meet the No RHR loop in operation SDM of LCO 3.1.1.

AND B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.8.2 Verify correct breaker alignment and indicated power 7 days are available to the required RHR pump that is not in operation.

SR 3.4.8.3 Verify RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

I Wolf Creek - Unit 1 3.4-18 Amendment No. 1,23-,41-,46-,

Attachment II to ET 14-0034 Page 6 of 11 ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4.

SR 3.5.2.1 Verif y the following valves are in the listed position 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power to the valve operator removed.

Number Position Function BN HV-8813 Open Safety Injection to RWST Isolation Valve EM HV-8802A Closed SI Hot Legs 2 & 3 Isolation Valve EM HV-8802B Closed SI Hot Legs I & 4 Isolation Valve EM HV-8835 Open Safety Injection Cold Leg Isolation Valve EJ HV-8840 Closed RHR/SI Hot Leg Recirc Isolation Valve EJ HV-8809A Open RHR to Accum Inject Loops 1 & 2 Isolation Valve EJ HV-8809B Open RHR to Accum Inject Loops 3 & 4 Isolation Valve

+

SR 3.5.2.2 Verify each ECCS manual, power operated, and 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 / FVerify ECCS piping i' full Of w*tz. locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.5.2.1 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the Inservice developed head. Testing Program (continued)

NOTE Not required to be met for system vent flow paths opened under administrative control.

Wolf Creek - Unit 1 3.5-4 Amendment No. 42-

Attachment II to ET 14-0034 Page 7 of 11 Containment Spray and Cooling Systems 3.6.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two containment cooling D.1 Restore one containment 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trains inoperable, cooling train to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C or D AND not met.

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Two containment spray F.1 Enter LCO 3.0.3. Immediately trains inoperable.

OR Any combination of three or more trains inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6. Verify each containment spray manual, power 31 day operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

INSERT 3.6-17 4.

SR 3.6.6.2 Operate each containment cooling train fan unit for 31 days

> 15 minutes.

(continued)

Wolf Creek - Unit 1 3.6-17 Amendment No. 42,-467- I

Attachment IIto ET 14-0034 Page 8 of 11 INSERT 3.6-17

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

Not required to be met for system vent flow paths opened under administrative control.

Attachment II to ET 14-0034 Page 9 of 11 Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.3 Not Used.

SR 3.6.6.4 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal to the Inservice the required developed head. Testing Program SR 3.6.6.5 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.

SR 3.6.6.6 Verify each containment spray pump starts 18 months automatically on an actual or simulated actuation signal.

SR 3.6.6.7 Verify each containment cooling train starts 18 months automatically and minimum cooling water flow rate is established on an actual or simulated actuation signal.

SR 3.6.6.8 Verify each spray nozzle is unobstructed. Following maintenance which could result in nozzle blockage Wolf Creek - Unit 1 3.6-18 Amendment No. 123, 167, 203

Attachment II to ET 14-0034 Page 10 of 11 RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of __1000 gpm.

SR 3.9.5.2 Verify required RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

I I I I. I. I I I I I I I I I I I 1 1 1 1 1 1 I I I I I I I I I Wolf Creek - Unit 1 3.9-8 Amendment No. 42-

Attachment II to ET 14-0034 Page 11 of 11 RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to restore Immediately one RHR loop to operation.

AND B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of > 1000 gpm.

SR 3.9.6.2 Verify correct breaker alignment and indicated power 7 days available to the required RHR pump that is not in operation.

Z!_ _ __ _ _

SR 3.9.6.3 Verify RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.I_____

Wolf Creek - Unit 1 3.9-10 Amendment No. 4--2

Attachment III to ET 14-0034 Page 1 of 43 ATTACHMENT III REVISED TECHNICAL SPECIFICATION PAGES

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.6 Containment Purge Isolation Instrumentation .................................. 3.3-45 3.3.7 Control Room Emergency Ventilation System (CREVS)

Actuation Instrumentation ........................................................... 3.3-49 3.3.8 Emergency Exhaust System (EES) Actuation Instrum entation ........................................................................... 3.3-54 3.4 REACTOR COOLANT SYSTEM (RCS) ................................................... 3.4-1 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits .................................................... 3.4-1 3.4.2 RCS Minimum Temperature for Criticality ........................................ 3.4-5 3.4.3 RCS Pressure and Temperature (P/T) Limits .................................. 3.4-6 3.4.4 RCS Loops - MODES 1 and 2 .......................................................... 3.4-8 3.4.5 RCS Loops - MODE 3 ....................................................................... 3.4-9 3.4.6 RCS Loops - MODE 4 ....................................................................... 3.4-12 3.4.7 RCS Loops- MODE 5, Loops Filled ................................................. 3.4-15 3.4.8 RCS Loops - MODE 5, Loops Not Filled .......................................... 3.4-18 3 .4 .9 P ressurize r ........................................................................................ 3 .4-20 3.4.10 Pressurizer Safety Valves ................................................................. 3.4-22 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) ....................... 3.4-24 3.4.12 Low Temperature Overpressure Protection (LTOP) System ........... 3.4-27 3.4.13 RCS Operational LEAKAGE ............................................................. 3.4-32 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage .................................. 3.4-34 3.4.15 RCS Leakage Detection Instrumentation ......................................... 3.4-38 3.4.16 RCS Specific Activity ......................................................................... 3.4-42 3.4.17 Steam Generator (SG) Tube Integrity ................................................ 3.4-44 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) .............................. 3.5-1 3 .5 .1 A ccum ulato rs .................................................................................... 3.5-1 3.5.2 EC C S - O perating ............................................................................. 3.5-3 3.5.3 EC C S - S hutdow n ............................................................................. 3.5-6 3.5.4 Refueling Water Storage Tank (RWST) ........................................... 3.5-8 3.5.5 S eal Injection Flow ............................................................................ 3.5-10 3.6 CONTAINMENT SYSTEMS ..................................................................... 3.6-1 3 .6 .1 C ontainm ent ...................................................................................... 3 .6-1 3.6.2 Containment Air Locks ...................................................................... 3.6-2 3.6.3 Containment Isolation Valves ........................................................... 3.6-7 3.6.4 Containment Pressure ...................................................................... 3.6-14 3.6.5 Containment Air Temperature .......................................................... 3.6-15 3.6.6 Containment Spray and Cooling Systems ........................................ 3.6-16 3.6.7 Spray Additive System ....................................................................... 3.6-20 Wolf Creek - Unit 1 ii Amendment No. 123, 131, 157, 164, 167 170,183,

RCS Loops - MODE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2- --------- NOTE-------

Only required if one RHR loop is OPERABLE.

Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. Required loops inoperable. B.1 Suspend operations that Immediately would cause introduction OR into the RCS, coolant with boron concentration less No RCS or RHR loop in than required to meet operation. SDM of LCO 3.1.1.

AND B.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.2 Verify SG secondary side narrow range water levels 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months are _>6% for required RCS loops.

SR 3.4.6.3 Verify correct breaker alignment and indicated power 7 days are available to the required pump that is not in operation.

(continued)

Wolf Creek - Unit 1 3.4-13 Amendment No. 123, !4,5,

RCS Loops - MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.6.4 NOTE----------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4.

Verify required RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

Wolf Creek - Unit 1 3.4-14 Amendment No. 123,4.5,

RCS Loops-MODE 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops - MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a. One additional RHR loop shall be OPERABLE; or

b. The secondary side wide range water level of at least two steam generators (SGs) shall be __66%.

NOTES --------------- ----

1. The RHR pump of the loop in operation may be removed from operation for _ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10OF below saturation temperature.

2. One required RHR loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3. No reactor coolant pump shall be started with any RCS cold leg temperature _<3680 F unless the secondary side water temperature of each SG is < 50°F above each of the RCS cold leg temperatures.

4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

APPLICABILITY: MODE 5 with RCS loops filled.

Wolf Creek - Unit 1 3.4-15 Amendment No. 123, 14.5, I

RCS Loops-MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop inoperable. A.1 Initiate action to restore a Immediately second RHR loop to AND OPERABLE status.

Required SGs secondary OR side water levels not within limits. A.2 Initiate action to restore Immediately required SG secondary side water levels to within limits.

B. Required RHR loops B.1 Suspend operations that Immediately inoperable, would cause introduction into the RCS, coolant with OR boron concentration less than required to meet No RHR loop in operation. SDM of LCO 3.1.1.

AND B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Wolf Creek - Unit 1 3.4-16 Amendment No. !23, !45, I

RCS Loops-MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.7.2 Verify SG secondary side wide range water level is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

>_66% in required SGs.

SR 3.4.7.3 Verify correct breaker alignment and indicated power 7 days are available to the required RHR pump that is not in operation.

SR 3.4.7.3 Verify required RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

Wolf Creek - Unit 1 3.4-17 Amendment No. 42-3,

RCS Loops - MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops - MODE 5, Loops Not Filled LCO 3.4.8 Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation.

NOTES----- ---------------

1. All RHR pumps may be removed from operation for _ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months provided:

a. The core outlet temperature is maintained at least 10°F below saturation temperature;

b. No operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the SDM of LCO 3.1.1; and

c. Reactor vessel water level is above the vessel flange.

2. One RHR loop may be inoperable for _:2 hours for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

APPLICABILITY: MODE 5 with RCS loops not filled.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop inoperable. A.1 Initiate action to restore Immediately RHR loop to OPERABLE status.

(continued)

Wolf Creek - Unit 1 3.4-18 Amendment No. 123, 131, 145, 155, I

RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend operations that Immediately inoperable, would cause introduction into the RCS, coolant with OR boron concentration less than required to meet the No RHR loop in operation SDM of LCO 3.1.1.

AND B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.8.2 Verify correct breaker alignment and indicated power 7 days are available to the required RHR pump that is not in operation.

SR 3.4.8.3 Verify RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

Wolf Creek - Unit 1 3.4-19 Amendment No. 123, 13!,4-.5,

Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:

a. Pressurizer water level < 92%; and

b. Two groups of backup pressurizer heaters OPERABLE with the capacity of each group _>150 kW.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water level not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months within limit.

AND A.2 Fully insert all rods. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND A.3 Place Rod Control System 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in a condition incapable of rod withdrawal.

AND A.4 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Wolf Creek - Unit 1 3.4-20 Amendment No. 41-2, I

Pressurizer 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One required group of B.1 Restore required group of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pressurizer heaters pressurizer heaters to inoperable. OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not AND met.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is *<92%. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.9.2 Verify capacity of each required group of pressurizer 18 months heaters is > 150 kW.

Wolf Creek - Unit 1 3.4-21 Amendment No. 1-23, I

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings 2411 psig and < 2509 psig.

APPLICABILITY: MODES 1, 2, and 3.

"I*IU I

- ---------------------------------- IM L i r-.

I-------------------------------------------------

The lift settings are not required to be within the LCO limits during MODE 3 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pressurizer safety A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Two or more pressurizer safety valves inoperable.

Wolf Creek - Unit 1 3.4-22 Amendment No. 1,2-, 33,-

Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE in In accordance with accordance with the Inservice Testing Program. the Inservice Following testing, lift settings shall be within +/- 1% of Testing Program 2460 psig.

Wolf Creek - Unit 1 3.4-23 Amendment No. 423,,43, I

Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1 and 2, MODE 3 with all RCS cold leg temperatures > 3680 F.

ACTIONS

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

Separate Condition entry is allowed for each PORV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and maintain power 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable and capable of to associated block valve.

being manually cycled.

B. One PORV inoperable and B.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not capable of being valve.

manually cycled.

AND B.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valve.

AND B.3 Restore PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

(continued)

Wolf Creek - Unit 1 3.4-24 Amendment No. 123, 155, I

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One block valve ---- NOTE ------------------

inoperable. Required Actions do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2.

C.1 Place associated PORV in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months manual control.

AND C.2 Restore block valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, AND or C not met.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Two PORVs inoperable E.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and not capable of being valves.

manually cycled.

AND E.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valves.

AND E.3 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND E.4 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Wolf Creek - Unit 1 3.4-25 Amendment No. 412-, I

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. More than one block valve ------------- NOTE ---------

inoperable. Required Actions do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2.

F.1 Place associated PORVs 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in manual control.

AND F.2 Restore one block valve to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not AND met.

G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 -------------- NOTE -----------

Not required to be performed with block valve closed in accordance with the Required Actions of this LCO.

Perform a complete cycle of each block valve. 92 days SR 3.4.11.2 Perform a complete cycle of each PORV. In accordance with the Inservice Testing Program Wolf Creek - Unit 1 3.4-26 Amendment No. --2Q, I

LTOP System 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.12 An LTOP System shall be OPERABLE with a maximum of zero safety injection pumps, one Emergency Core Cooling System (ECCS) centrifugal charging pump, and the normal charging pump capable of injecting into the RCS and the accumulators isolated and one of the following pressure relief capabilities:

a. Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR, or

b. Two residual heat removal (RHR) suction relief valves with setpoints

> 436.5 psig and _< 463.5 psig, or

c. One PORV with a lift setting within the limits specified in the PTLR and one RHR suction relief valve with a setpoint __436.5 psig and

_<463.5 psig, or

d. The RCS depressurized and an RCS vent of _> 2.0 square inches.

NOTES --------------------------

1. Two ECCS centrifugal charging pumps may be made capable of injecting for _ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for pump swap operation.

2. Two safety injection pumps and two ECCS centrifugal charging pumps may be made capable of injecting into the RCS: (a) in MODE 3 with any RCS cold leg temperature < 3680 F and ECCS pumps OPERABLE pursuant to LCO 3.5.2, "ECCS - Operating," and (b) for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entering MODE 4 from MODE 3 or until the temperature of one or more RCS cold leg decreases below 325 0 F, whichever comes first.

3. One or more safety injection pumps may be made capable of injecting into the RCS in MODES 5 and 6 when the RCS water level is below the top of the reactor vessel flange for the purpose of protecting the decay heat removal function.

4. Accumulator may be unisolated when accumulator pressure is less than the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

Wolf Creek - Unit 1 3.4-27 Amendment No. 423, 2,*7,

LTOP System 3.4.12 APPLICABILITY: MODE 3, with any RCS cold leg temperature __3680 F, MODE 4, MODE 5, MODE 6 when the reactor vessel head is on.

ACTIONS

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

LCO 3.0.4b. is not applicable when entering MODE 4 or MODE 3.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more safety A.1 Initiate action to verify a Immediately injection pumps capable of maximum of zero safety injecting into the RCS. injection pumps are capable of injecting into the RCS.

B. Two ECCS centrifugal B.1 Initiate action to verify a Immediately charging pumps capable of maximum of one ECCS injecting into the RCS. centrifugal charging pump and the normal charging pump capable of injecting into the RCS.

C. An accumulator not C.1 Isolate affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolated when the accumulator.

accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

(continued)

Wolf Creek - Unit 1 3.4-28 Amendment No. 123,155* 2 07- I

LTOP System 3.4.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Increase all RCS cold leg 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion temperatures to > 368 0 F.

Time of Condition C not met. OR D.2 Depressurize affected 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

E. One required RCS relief E.1 Restore required RCS 7 days valve inoperable in MODE relief valve to OPERABLE 3 or MODE 4. status.

F. One required RCS relief F.1 Restore required RCS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve inoperable in relief valve to OPERABLE MODE 5 or 6. status.

G. Two required RCS relief G.1 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months valves inoperable, establish RCS vent of

Ž 2.0 square inches.

OR Required Action and associated Completion Time of Condition A, B, D, E, or F not met.

OR LTOP System inoperable for any reason other than Condition A, B, C, D, E, or F.

Wolf Creek - Unit 1 3.4-29 Amendment No. 1-23, I

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of zero safety injection pumps are 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months capable of injecting into the RCS.

SR 3.4.12.2 Verify a maximum of one ECCS centrifugal charging 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months pump and the normal charging pump capable of injecting into the RCS.

SR 3.4.12.3 Verify each accumulator is isolated when 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

SR 3.4.12.4 Verify RHR suction isolation valves are open for each 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required RHR suction relief valve.

SR 3.4.12.5 Verify required RCS vent _ 2.0 square inches open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for vent pathway(s) not locked, sealed or otherwise secured in the open position AND 31 days for vent valve(s) locked, sealed or otherwise secured in the open position (continued)

Wolf Creek - Unit 1 3.4-30 Amendment No. 123, ,207, I

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.6 Verify PORV block valve is open for each required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months PORV.

SR 3.4.12.7 Not Used.

SR 3.4.12.8 ------------------ NOTE ------------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing any RCS cold leg temperature to _<368°F.

Perform a COT on each required PORV, excluding 31 days actuation.

SR 3.4.12.9 Perform CHANNEL CALIBRATION for each required 18 months PORV actuation channel.

Wolf Creek - Unit 1 3.4-31 Amendment No. 4-23, 1

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 1 gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; and

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within limits within limits.

for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limit.

Wolf Creek - Unit 1 3.4-32 Amendment No. 123,164, 1

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 S---NOTES -------.-......-----.- ----

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

2. Not applicable to primary to secondary LEAKAGE.

Verify RCS operational LEAKAGE is within limits by 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months performance of RCS water inventory balance.

SR 3.4.13.2 ------------------- NOTE -.................-------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary to secondary LEAKAGE is < 150 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months gallons per day through any one SG.

Wolf Creek - Unit 1 3.4-33 Amendment No. 23, 164., I

RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1, 2, and 3, MODE 4, except valves in the residual heat removal (RHR) flow path when in, or during the transition to or from, the RHR mode of operation.

ACTIONS

1. Separate Condition entry is allowed for each flow path.

2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths ----------- NOTE-----------

with leakage from one or Each valve used to satisfy Required more RCS PIVs not within Action A.1 must have been verified limit, to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary.

A.1 Isolate the high pressure 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months portion of the affected system from the low pressure portion by use of one deactivated remote manual or check valve.

AND A.2. Restore RCS PIV to within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months limits.

(continued)

Wolf Creek - Unit 1 3.4-34 Amendment No. 42-, I

RCS PIV Leakage 3.4.14 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. RHR suction isolation C.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valve interlock function penetration by use of one inoperable, deactivated remote manual valve.

Wolf Creek - Unit 1 3.4-35 Amendment No. 1-2-, I

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 --------------

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 In accordance with

_<0.5 gpm per nominal inch of valve size up to a the Inservice maximum of 5 gpm at an RCS pressure _> 2215 psig Testing Program, and _<2255 psig. and 18 months AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, and if leakage testing has not been performed in the previous 9 months AND Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following check valve actuation due to flow through the valve (continued)

Wolf Creek - Unit 1 3.4-36 Amendment No. 1-2, I

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.14.2 Verify RHR suction isolation valve interlock prevents 18 months the valves from being opened with a simulated or actual RCS pressure signal __425 psig except when the valves are open to satisfy LCO 3.4.12.

Wolf Creek - Unit 1 3.4-37 Amendment No. 1-2, I

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. The containment sump level and flow monitoring system;

b. One containment atmosphere particulate radioactivity monitor; and

c. One containment air cooler condensate monitoring system.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required containment A.1 ----- NOTE-------

sump level and flow Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months monitoring system after establishment of inoperable, steady state operation.

Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND

..------- NOTE--------

The Completion Time is extended beyond the 30 days until startup from a plant shutdown or startup from Refueling Outage 20.

A.2 Restore required 30 days containment sump level and flow monitoring system to OPERABLE status.

(continued)

Wolf Creek - Unit 1 3.4-38 Amendment No. 123,155, 166, 211, I

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required containment B. 1.1 Analyze samples of the Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months atmosphere particulate containment atmosphere.

radioactivity monitor inoperable. OR B.1.2 --------- NOTE --------------

Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND B.2.1 Restore required 30 days containment atmosphere particulate radioactivity monitor to OPERABLE status.

OR B.2.2 Verify containment air 30 days cooler condensate monitoring system is OPERABLE.

C. Required containment C.1 Perform SR 3.4.15.1. Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months cooler condensate monitoring system OR inoperable.

C.2 --------- NOTE-------

Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Perform SR 3.4.13.1.

(continued)

Wolf Creek - Unit 1 3.4-39 Amendment No. 123, 66, I

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required containment D.1 Restore required 30 days atmosphere particulate containment atmosphere radioactivity monitor particulate radioactivity inoperable, monitor to OPERABLE status.

AND OR Required containment cooler condensate D.2 Restore required 30 days monitoring system containment cooler inoperable, condensate monitoring system to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. All required monitoring F.1 Enter LCO 3.0.3. Immediately methods inoperable.

Wolf Creek - Unit 1 3.4-40 Amendment No. 123,466, 1

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months containment atmosphere particulate radioactivity monitor.

SR 3.4.15.2 Perform COT of the required containment 92 days atmosphere particulate radioactivity monitor.

SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required 18 months containment sump level and flow monitoring system.

SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required 18 months containment atmosphere particulate radioactivity monitor.

SR 3.4.15.5 Perform CHANNEL CALIBRATION of the required 18 months containment cooler condensate monitoring system.

Wolf Creek - Unit 1 3.4-41 Amendment No. 423, 166,

RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 RCS DOSE EQUIVALENT 1-131 and DOSE EQUIVALENT XE-133 specific activity shall be within limits.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT 1-131 -------- NOTE-------

not within limit. LCO 3.0.4c. is applicable.

A.1 Verify DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT 1-131

< 60 ýiCi/gm.

AND A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT 1-131 to within limit.

B. DOSE EQUIVALENT ------------------ NOTE----------

XE-1 33 not within limit. LCO 3.0.4c. is applicable.

B.1 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT XE-133 to within limit.

(continued)

Wolf Creek - Unit 1 3.4-42 Amendment No. 123, !55, 170, I

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B AND not met.

C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR DOSE EQUIVALENT 1-131

> 60 .iCi/gm.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 ---------------- NOTE -----------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT XE-133 7 days specific activity _ 500 jiCi/gm.

SR 3.4.16.2 ------------------ NOTE----------

Only required to be performed in MODE 1.

14 days Verify reactor coolant DOSE EQUIVALENT 1-131 AND specific activity < 1.0 j.Ci/gm.

Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of >_15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period Wolf Creek - Unit 1 3.4-43 Amendment No. 23, 1:70, I

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained.

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

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS N

Separate Condition entry is allowed for each SG tube.

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

AND A.2 Plug the affected tube(s) in Prior to entering accordance with the Steam MODE 4 following Generator Program. the next refueling outage or SG tube inspection B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

Wolf Creek - Unit 1 3.4-44 Amendment No. 164,17-0, 199, 1

SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with the In accordance Steam Generator Program. with the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that satisfies the Prior to entering tube plugging criteria is plugged in accordance with MODE 4 following the Steam Generator Program. a SG tube inspection Wolf Creek - Unit 1 3.4-45 Amendment No. 164-,-170, 199, I

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verilfy the following valves are in the listed position 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power to the valve operator removed.

Number Position Function BN HV-8813 Open Safety Injection to RWST Isolation Valve EM HV-8802A Closed SI Hot Legs 2 & 3 Isolation Valve EM HV-8802B Closed SI Hot Legs 1 & 4 Isolation Valve EM HV-8835 Open Safety Injection Cold Leg Isolation Valve EJ HV-8840 Closed RHR/Sl Hot Leg Recirc Isolation Valve EJ HV-8809A Open RHR to Accum Inject Loops 1 & 2 Isolation Valve EJ HV-8809B Open RHR to Accum Inject Loops 3 & 4 Isolation Valve

+

SR 3.5.2.2 Not required to be met for system vent flow paths opened under administrative control.

Verify each ECCS manual, power operated, and 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify ECCS locations susceptible to gas 92 days accumulation are sufficiently filled with water.

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 the Inservice developed head. Testing Program (continued)

Wolf Creek - Unit 1 3.5-4 Amendment No. --2-,

Containment Spray and Cooling Systems 3.6.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two containment cooling D.1 Restore one containment 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trains inoperable, cooling train to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C or D AND not met.

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Two containment spray F.1 Enter LCO 3.0.3. Immediately trains inoperable.

OR Any combination of three or more trains inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 ----------- .....------------

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

Not required to be met for system vent flow paths opened under administrative control.

Verify each containment spray manual, power 31 day operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

(continued)

Wolf Creek - Unit 1 3.6-17 Amendment No. !23,!6.7,

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.2 Operate each containment cooling train fan unit for 31 days

> 15 minutes.

SR 3.6.6.3 Not Used.

SR 3.6.6.4 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal to the Inservice the required developed head. Testing Program SR 3.6.6.5 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.

SR 3.6.6.6 Verify each containment spray pump starts 18 months automatically on an actual or simulated actuation signal.

SR 3.6.6.7 Verify each containment cooling train starts 18 months automatically and minimum cooling water flow rate is established on an actual or simulated actuation signal.

SR 3.6.6.8 Verify each spray nozzle is unobstructed. Following maintenance which could result in nozzle blockage Wolf Creek - Unit 1 3.6-18 Amendment No. 23,* .67, 2O0,

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.9 Verify containment spray locations susceptible to gas 92 days accumulation are sufficiently filled with water.

Wolf Creek - Unit 1 3.6-19 Amendment No. 123,!6-7,203,

Spray Additive System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Spray Additive System LCO 3.6.7 The Spray Additive System shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spray Additive System A.1 Restore Spray Additive 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. System to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Verify each spray additive manual, power operated, 31 days and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

(continued)

Wolf Creek - Unit 1 3.6-20 Amendment No. 123, 167, I

Spray Additive System 3.6.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.7.2 Verify spray additive tank solution volume is Ž 4340 184 days gal and

4540 gal.

SR 3.6.7.3 Verify spray additive tank solution concentration is 184 days

Ž>28% and

31% by weight.

SR 3.6.7.4 Verify each spray additive automatic valve in the flow 18 months path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.7.5 Verify spray additive flow rate from each solution's 5 years flow path.

Wolf Creek - Unit 1 3.6-21 Amendment No. 123,167, I

RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of -e1000 gpm.

SR 3.9.5.2 Verify required RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

Wolf Creek - Unit 1 3.9-8 Amendment No. 4-2-,

RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to restore Immediately one RHR loop to operation.

AND B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of > 1000 gpm.

SR 3.9.6.2 Verify correct breaker alignment and indicated power 7 days available to the required RHR pump that is not in operation.

SR 3.9.6.3 Verify RHR loop locations susceptible to gas 31 days accumulation are sufficiently filled with water.

Wolf Creek - Unit 1 3.9-10 Amendment No. 42-3,

Attachment IV to ET 14-0034 Page 1 of 24 ATTACHMENT III PROPOSED TS BASES CHANGES (FOR INFORMATION ONLY)

Attachment IVto ET 14-0034 Page 2 of 24 RCS Loops-MODE 4 B 3.4.6 BASES LCO The purpose of this LCO is to require that at least two loops be OPERABLE in MODE 4 and that one of these loops be in operation. The LCO allows the two loops that are required to be OPERABLE to consist of any combination of RCS loops and RHR loops. Any one loop in operation provides enough flow to remove the decay heat from the core with forced circulation. An additional loop is required to be OPERABLE to provide redundancy for heat removal.

Note 1 permits all RCPs or RHR pumps to be removed from operation for

< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period. The purpose of the Note is to permit tests that are required to be performed without flow or pump noise. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months time period is adequate to perform the necessary testing, and operating experience has shown that boron stratification is not a problem during this short period with no forced flow.

Utilization of Note I is permitted provided the following conditions are met along with any other conditions imposed by test procedures:

a. No operations are permitted that would dilute the RCS boron concentration with coolant at boron concentrations less than required to assure the SDM of LCO 3.1.1, thereby maintaining the margin to criticality. Boron reduction with coolant at boron concentrations less than required to assure the SDM is maintained is prohibited because a uniform concentration distribution throughout the RCS cannot be ensured when in natural circulation; and

b. Core outlet temperature is maintained at least 1 0°F below saturation temperature, so that no vapor bubble may form and possibly cause a natural circulation flow obstruction.

Note 2 requires that the secondary side water temperature of each SG be

_<50°F above each of the RCS cold leg temperatures before the start of an RCP with any RCS cold leg temperature _ 368 0 F. This restraint is to prevent a low temperature overpressure event due to a thermal transient when an RCP is started.

An OPERABLE RCS loop is comprised of an OPERABLE RCP and an Management of gas voids Is OPERABLE SG, which has the minimum water level specified in important to RHR System SR 3.4.6.2.

OPERABILIY. Simila for the RHR System, an OPERABLE RHR loop comprises an OPERAB HR pump capable of providing forced flow to an OPERABLE R heat exchanger. RCPs and RHR pumps are OPERABLE if they capable of being powered and are able to provide forced flow if required.

Wolf Creek - Unit 1 B 3.4.6-2 Revision 29

Attachment IV to ET 14-0034 Page 3 of 24 RCS Loops-MODE 4 B 3.4.6 BASES ACTIONS B.1 and B.2 (continued) at least one RCP for proper mixing, so that inadvertent criticality may be prevented. Suspending the introduction into the RCS, coolant with boron concentration less than required to meet the minimum SDM of LCO 3.1.1 is required to assure continued safe operation. With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations.

The immediate Completion Times reflect the importance of maintaining operation for decay heat removal. The action to restore must be continued until one loop is restored to OPERABLE status and operation.

SURVEILLANCE SR 3.4.6.1 REQUIREMENTS This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one RCS or RHR loop is in operation. Verification may include flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient considering other indications and alarms available to the operator in the control room to monitor RCS and RHR loop performance.

SR 3.4.6.2 SR 3.4.6.2 requires verification of SG OPERABILITY. SG OPERABILITY is verified by ensuring that the secondary side narrow range water level is

> 6% for required RCS loops. If the SG secondary side narrow range water level is < 6%, the tubes may become uncovered and the associated loop may not be capable of providing the heat sink necessary for removal of decay heat. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is considered adequate in view of other indications available in the control room to alert the operator to the loss of SG level.

SR 3.4.6.3 Verification that the required pump is OPERABLE ensures that an additional RCS or RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the required pump. The Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.

WolfERee nT1 B 3.4.6-4Reion1 Wolf Creek - Unit 1 B 3.4.6-4 Revision 12

Attachment IVto ET 14-0034 Page 4 of 24 INSERT B 3.4.6-4 SR 3.4.6.4 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the required RHR loop(s) and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.

Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The RHR System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR System is not rendered inoperable by the accumulated 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.

RHR System 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.

This SR is modified by a Note that states the SR is not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4. In a rapid shutdown, there may be insufficient time to verify all susceptible locations prior to entering MODE 4.

The 31 day Frequency takes into consideration the gradual nature of gas accumulation in the RHR System piping and the procedural controls governing system operation.

Attachment IVto ET 14-0034 Page 5 of 24 RCS Loops - MODE 5, Loops Filled B 3.4.7 BASES LCO b. Core outlet temperature is maintained at least 1 0°F below (continued) saturation temperature, so that no vapor bubble may form and possibly cause a natural circulation flow obstruction.

Note 2 allows one RHR loop to be inoperable for a period of up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , provided that the other RHR loop is OPERABLE and in operation. This permits periodic surveillance tests to be performed on the inoperable loop during the only time when such testing is safe and possible.

Note 3 requires that the secondary side water temperature of each SG be

< 50°F above each of the RCS cold leg temperatures before the start of a reactor coolant pump (RCP) with any RCS cold leg temperature _<3680 F.

This restriction is to prevent a low temperature overpressure event due to a thermal transient when an RCP is started.

Note 4 provides for an orderly transition from MODE 5 to MODE 4 during a planned heatup by permitting removal of RHR loops from operation when at least one RCS loop is in operation. This Note provides for the transition to MODE 4 where an RCS loop is permitted to be in operation and replaces the RCS circulation function provided by the RHR loops.

RHR pumps are OPERABLE if they are capable of being powered and are able to provide forced flow if required. When both RHR loops (or trains) are required to be OPERABLE, the associated Component Cooling Water (CCW) train is required to be capable of performing its related support function(s). The heat sink for the CCW System is normally provided by the Service Water System or Essential Service Water (ESW)

System, as determined by system availability. In MODES 5 and 6, one Diesel Generator (DG) is required to be OPERABLE per LCO 3.8.2, "AC Managemet of gas voids Is ources - Shutdown." The same ESW train is required to be capable of importa, t to RHR System pe s related support function(s) to support DG OPERABILITY. A

....... L.r.. Service Water be utilized to support RHR OPERABILITY if the associated ESW train is no e of performing its related support function(s). A SG can perform as a he

via natural circulation when it has an adequate water level and is OPERABL .

APPLICABILITY In MODE 5 with RCS loops filled, this LCO requires forced circulation of the reactor coolant to remove decay heat from the core and to provide proper boron mixing. One loop of RHR provides sufficient circulation for these purposes. However, one additional RHR loop is required to be OPERABLE, or the secondary side wide range water level of at least two SGs is required to be _Ž66%.

Operation in other MODES is covered by:

LCO 3.4.4, "RCS Loops - MODES 1 and 2";

Wolf Creek - Unit 1 B 3.4.7-3 Revision 63

Attachment IV to ET 14-0034 Page 6 of 24 RCS Loops - MODE 5, Loops Filled B 3.4.7 BASES SURVEILLANCE SR 3.4.7.2 REQUIREMENTS (continued) Verifying that at least two SGs are OPERABLE by ensuring their secondary side wide range water levels are > 66% ensures an alternate decay heat removal method is available via natural circulation in the event that the second RHR loop is not OPERABLE. If both RHR loops are OPERABLE, this Surveillance is not needed. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is considered adequate in view of other indications available in the control room to alert the operator to the loss of SG level.

SR 3.4.7.3 Verification that a second RHR pump is OPERABLE ensures that an additional pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the RHR pump.

If secondary side wide range water level is > 66% in at least two SGs, this Surveillance is not needed. The Frequency of 7 days is considered areasonable Shown to beinacceptable view of other administrative by operating controls available and has been experience.

REFERENCES 1. USAR, Section 15.4.6.

2. NRC Information Notice 95-35, "Degraded Ability of SGs to Remove Decay Heat by Natural Circulation."

Wolf Creek - Unit 1 B 3.4.7-5 Revision 12

Attachment IVto ET 14-0034 Page 7 of 24 INSERT B 3.4.7-5 SR 3.4.7.4 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the required RHR loop(s) and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.

Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The RHR System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR System is not rendered inoperable by the accumulated 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.

RHR System 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 31 day Frequency takes into consideration the gradual nature of gas accumulation in the RHR System piping and the procedural controls governing system operation.

Attachment IV to ET 14-0034 Page 8 of 24 RCS Loops - MODE 5, Loops Not Filled B 3.4.8 BASES LCO Note I permits all RHR pumps to be removed from operation for _<1 hour.

(continued) The circumstances for stopping both RHR pumps are to be limited to situations when the outage time is short and core outlet temperature is maintained at least 10°F below saturation temperature. The Note prohibits boron dilution with coolant at boron concentrations less than required to assure the SDM of LCO 3.1.1 is maintained or draining operations when RHR forced flow is stopped. The Note requires reactor vessel water level be above the vessel flange to ensure the operating RHR pump will not be intentionally deenergized during mid-loop operations.

Note 2 allows one RHR loop to be inoperable for a period of

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , provided that the other loop is OPERABLE and in operation. This permits periodic surveillance tests to be performed on the inoperable loop during the only time when these tests are safe and possible.

An OPERABLE RHR loop is comprised of an OPERABLE RHR pump capable of providing forced flow to an OPERABLE RHR heat exchanger.

RHR pumps are OPERABLE if they are capable of being powered and are able to provide flow if required. When both RHR loops (or trains) are required to be OPERABLE, the associated Component Cooling Water (CCW) train is required to be capable of performing its related support function(s). The heat sink for the CCW System is normally provided by the Service Water System or Essential Service Water (ESW) System, as determined by system availability. In MODES 5 and 6, one Diesel Generator (DG) is required to be OPERABLE per LCO 3.8.2, "AC Sources anagement of gas voids is hutdown." The same ESW train is required to be capable of performing mPoRHRLsYs related support function(s) to support DG OPERABILITY. A Service Wa rain can be utilized to support RHR OPERABILITY if the associa SW train is not capable of performing its related support function(s).

APPLICABILITY In MODE 5 with loops not filled, this LCO requires core heat removal and coolant circulation by the RHR System. One RHR loop provides sufficient capability for this purpose. However, one additional RHR loop is required to be OPERABLE to meet single failure considerations.

Operation in other MODES is covered by:

LCO 3.4.4, "RCS Loops - MODES 1 and 2";

LCO 3.4.5, "RCS Loops - MODE 3";

LCO 3.4.6, "RCS Loops - MODE 4";

LCO 3.4.7, "RCS Loops - MODE 5, Loops Filled";

LCO 3.9.5, "Residual Heat Removal (RHR) and Coolant Circulation - High Water Level" (MODE 6); and LCO 3.9.6, "Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level" (MODE 6).

Wolf Creek - Unit I B 3.4.8-2 Revision 62

Attachment IV to ET 14-0034 Page 9 of 24 RCS Loops - MODE 5, Loops Not Filled B 3.4.8 BASES SURVEILLANCE SR 3.4.8.2 REQUIREMENTS (continued) Verification that a second RHR pump is OPERABLE ensures that an additional pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the RHR pump.

(The Frequency of 7 days is considered reasonable in view of other 3administrative controls available and has been shown to be acceptable by operating experience.

REFERENCES 1. USAR, Section 15.4.6.

Wolf Creek - Unit I B 3.4.8-4 Revision 42 1

Attachment IVto ET 14-0034 Page 10 of 24 INSERT B 3.4.8-4 SR 3.4.8.3 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR loops and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.

Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The RHR System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR System is not rendered inoperable by the accumulated 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.

RHR System 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 31 day Frequency takes into consideration the gradual nature of gas accumulation in the RHR System piping and the procedural controls governing system operation.

Attachment IVto ET 14-0034 Page 11 of 24 ECCS - Operating B 3.5.2 BASES LCO In MODES 1, 2, and 3, two independent (and redundant) ECCS trains are required to ensure that sufficient ECCS flow is available, assuming a single failure affecting either train. Additionally, individual components within the ECCS trains may be called upon to mitigate the consequences of other transients and accidents.

In MODES 1, 2, and 3, an ECCS train consists of a centrifugal charging subsystem, an SI subsystem, and an RHR subsystem. Each train includes the piping, instruments, and controls to ensure an OPERABLE flow path capable of taking suction from the RWST upon an SI signal and automatically transferring suction to the containment sump.

During an event requiring ECCS actuation, a flow path is required to provide an abundant supply of water from the RWST to the RCS via the aECCS pumps and their respective supply headers to each of the four cold Important to ECCS OPERABILITY. leg injection nozzles. In the long term, this flow path may be switched to from the containment sump and to supply its flow to the RCS hot and co egs.

The LCO requires the OPERABILITY of a number of independent subsystems. Due to the redundancy of trains and the diversity of subsystems, the inoperability of one component in a train does not render the ECCS incapable of performing its function. Neither does the inoperability of two different components, each in a different train, necessarily result in a loss of function for the ECCS. Reference 6 describes situations in which one component, such as an RHR crossover valve, can disable both ECCS trains.

During recirculation operation, the flow path for each train must maintain its designed independence to ensure that no single failure can disable both ECCS trains.

As indicated in Note 1, the SI flow paths may be isolated for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in MODE 3, under controlled conditions, to perform pressure isolation valve testing per SR 3.4.14.1. The flow path is readily restorable from the control room, and a single active failure is not assumed coincident with this testing (Ref. 7). Therefore, the ECCS trains are considered OPERABLE during this isolation.

As indicated in Note 2, operation in MODE 3 with ECCS pumps made incapable of injecting, pursuant to LCO 3.4.12, "Low Temperature Overpressure Protection (LTOP) System," is necessary for plants with an LTOP arming temperature at or near the MODE 3 boundary temperature of 3500 F. LCO 3.4.12 requires that certain pumps be rendered incapable of injecting at and below the LTOP arming temperature. When this temperature is at or near the MODE 3 boundary temperature, time is needed to restore the inoperable pumps to OPERABLE status.

Wolf Creek - Unit 1 B 3.5.2-5 Revision 41

Attachment IV to ET 14-0034 Page 12 of 24 ECCS - Operating B 3.5.2 BASES SURVEILLANCE SR 3.5.2.2 REQUIREMENTS (continued) Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation. This SR does not apply to valves that The Survliance Is modified by are locked, sealed, or otherwise secured in position, since these were a Note which exempts system verified to be in the correct position prior to locking, sealing, or securing.

vent flow paths opened under This SR does not apply to manual veniYdrain valves, and to valves that

.administrative control. The cannot be inadvertently misaligned such as check valves. A valve that administrative control should be proceduralized and include receives an actuation signal is allowed to be in a nonaccident position stationing a dedicated Individual provided the valve will automatically reposition within the proper stroke at inthecontinuous Sis system vent flow path who communication time. This Surveillance does not require any testing or valve with the operators inthe controlon manipulation. Rather, it involves verification that those valves capable of room. This Individual will have a being mispositioned are in the correct position. The 31 day Frequency is method to rapidly dose the system appropriate because the valves are operated under administrative control, vent flow path ifdirected. and an improper valve position would only affect a single train. This "Frequency has been shown to be acceptable through operating e*xperience.

4i2trnýZa2?

SR 3.5.2.3 Tk -- r*p ............. 15 I

....h, ...o. pth..

i----" Path.. pipin..g Iii g hha t . otential to develop

--- L L-- L-P'%f 'q II voids and pockets of

"-V- ...RIL

.. ..M... "" .I P J" .;.

entrained gases. 'it is .ii, ill ii =; l;t U1;;Z L..t.t H 6J 3 3

.awa,..,t a_

iti;i7 4k .

4 A A furetien under all LOCA and non LOCGA oonditione that rzquirz m~akcup to the RCS. Maintaining the piping frzmn the ECCS pumps te the RCC suffliently full of water enourzo that the eyetem will peoferm prporldy, injzting ite full capapity inito the RIGS upon doman8d. This GR issati'io by YSofyRi@i that RHR RAnd SI pumRp 68cngc and Hi

&oGccbl EGC cuction GAnd diSCharg. piping high POin YGontc aro suffioiontly full ef water b venfingq and/or- ultraponi: tcotfing (U1T). The deoign of the eentrifugial SPreventing and managing gas Intrusion and accumulation is ncessary for properoprtn of the ECCS and may also WVI*IIVI II*ll I

,%DrQLL, A r -I A pabeg l .,~. i -..*-...,*.

ith.o.ut

.... ar high.....r d.. to p..nn.l. Th.is.wia.. prevent water hammer, pump cavitation, and pumping of noncondensible gas (8.g., air, nitrogen, or hyd"cgen) into the reactor vessel following a-- f signal er during ghut~dewl eaeJim Th31 . day Frqec takeso *.IL onIario ma J ---- I naAr -raa camiaininm 00 eO% Aý ana me aroooaur~i coniroic ao~omina c~cmom opor~imion.

GNSETB3.6.2-8 Wolf Creek - Unit 1 B 3.5.2-8 Revision 38

Attachment IVto ET 14-0034 Page 13 of 24 INSERT B 3.5.2-8 Selection of ECCS locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The ECCS is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. In conjunction with or in lieu of venting, Ultrasonic Testing (UT) may be performed to verify the ECCS pumps and associated piping are sufficiently full of water. The design of the centrifugal charging pump is such that significant noncondensible gases do not collect in the pump. Therefore, it is unnecessary to require periodic pump casing venting to ensure the centrifugal charging pump will remain OPERABLE. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump),

the Surveillance is not met. If it is determined by subsequent evaluation that the ECCS is not rendered inoperable by the accumulated 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 92 day Frequency takes into consideration the plant specific nature of gas accumulation in the ECCS piping and the procedural controls governing system operation.

Attachment IVto ET 14-0034 Page 14 of 24 ECCS - Shutdown B 3.5.3 BASES LCO In MODE 4, an ECCS train consists of a centrifugal charging subsystem (continued) and an RHR subsystem. Each train includes the piping, instruments, and controls to ensure an OPERABLE flow path capable of taking suction from the RWST and transferring suction to the containment sump.

During an event requiring ECCS actuation, a flow path is required to Managemertof gasvosidsIs provide an abundant supply of water from the RWST to the RCS via the important to ECCS ECCS pumps and their respective supply headers to two cold leg injection OPERABILITY. nozzles. In the long term, this flow path may be switched to take its rom the containment sump and to deliver its flow to the RCS hot This LCO is modified by a Note that allows an RHR train to be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned (remote or local) to the ECCS mode of operation and not otherwise inoperable. This allows operation in the RHR mode during MODE 4. Only one RHR train is placed into operation to reduce RCS temperature. For an RHR train to be considered OPERABLE during shutdown, the train cannot be placed in service until RCS temperature is less than 225 OF (plant computer)/215 OF (main control board). For an RHR train to be considered OPERABLE during startup, the train must be isolated from the RCS prior to RCS temperature exceeding 225 OF (plant computer)/215 OF (main control board).

APPLICABILITY In MODES 1, 2, and 3, the OPERABILITY requirements for ECCS are covered by LCO 3.5.2.

In MODE 4 with RCS temperature below 350°F, one OPERABLE ECCS train is acceptable without single failure consideration, on the basis of the stable reactivity of the reactor and the limited core cooling requirements.

In MODES 5 and 6, plant conditions are such that the probability of an event requiring ECCS injection is extremely low. Core cooling requirements in MODE 5 are addressed by LCO 3.4.7, "RCS Loops -

MODE 5, Loops Filled," and LCO 3.4.8, "RCS Loops - MODE 5, Loops Not Filled." MODE 6 core cooling requirements are addressed by LCO 3.9.5, "Residual Heat Removal (RHR) and Coolant Circulation - High Water Level," and LCO 3.9.6, "Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level."

ACTIONS A Note prohibits the application of LCO 3.0.4b. to an inoperable ECCS centrifugal charging pump subsystem when entering MODE 4. There is an increased risk associated with entering MODE 4 from MODE 5 with an Wolf Creek - Unit I B 3.5.3-2 Revision 56

Attachment IV to ET 14-0034 Containment Spray and Cooling Systems Page 15 of 24 B 3.6.6 BASES APPLICABLE The modeled Containment Spray System actuation from the containment SAFETY ANALYSES analysis is based on a response time associated with exceeding the (continued) containment High-3 pressure setpoint to achieving full flow through the containment spray nozzles.

The Containment Spray System total response time includes diesel generator (DG) startup (for loss of offsite power), sequenced loading of equipment, containment spray pump startup, and spray line filling (Ref. 4).

Containment cooling train performance for post accident conditions is given in Reference 4. The result of the analysis is that each train can provide 100% of the required peak cooling capacity during the post accident condition. The train post accident cooling capacity under varying containment ambient conditions, required to perform the accident analyses, is also shown in Reference 4.

The modeled Containment Cooling System actuation from the containment analysis is based upon a response time associated with receipt of an SI signal to achieving full Containment Cooling System air and safety grade cooling water flow. The Containment Cooling System total response time of 70 seconds, includes signal delay, DG startup (for loss of offsite power), and Essential Service Water pump startup times and line refill (Ref. 4).

The Containment Spray System and the Containment Cooling System satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii).

LCO During a DBA, a minimum of one containment cooling train and one containment spray train is required to maintain the containment peak pressure and temperature below the design limits (Ref. 3). Additionally, one containment spray train is also required to remove iodine from the containment atmosphere and maintain concentrations below those assumed in the safety analysis. With the Spray Additive System inoperable, a containment spray train is still available and would remove some iodine from the containment atmosphere in the event of a DBA. To ensure that these requirements are met, two containment spray trains and two containment cooling trains must be OPERABLE. Therefore, in the event of an accident, at least one train in each system operates, assuming the worst case single active failure occurs.

Management off gas vods Is Each Containment Spray System typically includes a spray pump, spray important to Containment headers, eductor, nozzles, valves, piping, instruments, and controls to Spray System OPERBILITY. ensure an OPERABLE flow path capable of taking suction from the on an ESF actuation signal and manually transferring to the

~~~~~containment s u---t ----

A containment cooling train typically includes cooling coils, dampers, two fans, instruments, and controls to ensure an OPERABLE flow path.

Wolf Creek - Unit 1 B 3.6.6-4 Revision 42

Attachment IV to ET 14-0034 Page 16 of 24 Containment Spray and Cooling Systems B 3.6.6 BASES ACTIONS F.1 (continued)

With two containment spray trains or any combination of three or more containment spray and cooling trains inoperable, the unit is in a condition outside the accident analysis. Therefore, LCO 3.0.3 must be entered immediately.

SURVEILLANCE SR 3.6.6.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the containment spray flow path provides assurance that the proper flow paths will exist for Containment Spray System operation. The correct alignment for the Containment Cooling System valves is provided in SR 3.7.8.1. This SR does not apply to manual The Surveillance is modif-ed by a Note YvenYrain valves and to valves that cannot be advertently misaligned which exempts system vent flow paths such as check valves. This SR does not apply to valves that are locked, opened under administrative control. sealed, or otherwise secured in position, since these were verified to be in The administrative control should be the correct position prior to locking, sealing, or securing. This SR does procedurallized and include stationing a not require any testing or valve manipulation. Rather, it involves dedicated individual at the system vent v flow path who is Incontinuous verification, through a system walkdown (which may include the use of communication with the operators in the local or remote indicators), that those valves outside containment and control room. This individual will have a capable of potentially being mispositioned are in the correct position. The method to rapidly close the system vent P"flow path Ifdirected.

31 day Frequency is based on engineering judgement, is consistent with flw padministrative controls governing valve operation, and ensures correct valve positions.

SR 3.6.6.2 Operating each containment cooling train fan unit for > 15 minutes ensures that all fan units are OPERABLE. It also ensures the abnormal conditions or degradation of the fan unit can be detected for corrective action. The 31 day Frequency was developed considering the known reliability of the fan units and controls, the two train redundancy available, and the low probability of significant degradation of the containment cooling train occurring between surveillances. It has also been shown to be acceptable through operating experience.

SR 3.6.6.3 Not Used.

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 BASES Wolf Creek - Unit 1 B 3.6.6-7 Revision 0

Attachment IVto ET 14-0034 Containment Spray and Cooling Systems Page 17 of 24 B 3.6.6 BASES SURVEILLANCE SR 3.6.6.8 REQUIREMENTS (continued) With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections. This SR ensures that each spray nozzle is unobstructed and provides assurance that spray coverage of the containment during an accident is not degraded. Due to the passive design of the nozzle, a confirmation of OPERABILITY following maintenance activities that can result in obstruction of spray nozzle flow is considered adequate to detect obstruction of the nozzles. Confirmation that the spray nozzles are unobstructed may be obtained by utilizing foreign material exclusion (FME) controls during maintenance, a visual inspection of the affected portions of the system, or by an air or smoke flow test following maintenance involving opening portions of the system downstream of the containment isolation valves or draining of the filled portions of the system inside containment. Maintenance that could result in nozzle blockage is generally a result of a loss of foreign material control or a flow of borated water through a nozzle. Should either of these events occur, a supervisory evaluation will be required to determine whether nozzle blockage is a possible result of the event. For the loss of FME event, an inspection or flush of the affected portions of the system should be adequate to confirm that the spray nozzles are unobstructed since water flow would be required to transport any debris to the spray nozzles. An air flow or smoke test may not be appropriate for a loss of FME event but may be appropriate for the case where borated water inadvertently flows through the nozzles.

~h.

INSET 83.6.6-9 REFERENCES 1. 10 CFR 50, Appendix A, GDC 38, GDC 39, GDC 40, GDC 41. GDC 42, and GDC 43, and GDC 50.

2. 10 CFR 50, Appendix K.

3. USAR, Section 6.2.1.

4. USAR, Section 6.2.2.

5. ASME Code for Operation and Maintenance of Nuclear Power Plants.

6. Performance Improvement Request 2002-0945.

Wolf Creek - Unit 1 B 3.6.6-9 Revision 58

Attachment IVto ET 14-0034 Page 18 of 24 INSERT B 3.6.6-9 SR 3.6.6.9 Containment Spray System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the containment spray trains and may also prevent water hammer and pump cavitation.

Selection of Containment Spray System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The Containment Spray System is OPERABLE when it is sufficiently filled with water.

Acceptance criteria are established for the volume of accumulated gas at susceptible locations.

If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the Containment Spray System is not rendered inoperable by the accumulated 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.

Containment Spray System locations susceptible to gas accumulation are monitored and, ifgas 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 92 day Frequency takes into consideration the plant specific nature of gas accumulation in the Containment Spray System piping and the procedural controls governing system operation.

Attachment IV to ET 14-0034 Page 19 of 24 RHR and Coolant Circulation - High Water Level B 3.9.5 BASES LCO removal capability. At least one RHR loop must be OPERABLE (continued) and in operation to provide:

a. Removal of decay heat;

b. Mixing of borated coolant to minimize the possibility of criticality; and Maaeeto a od s C niainof reactor coolant temperature.

OPERABILITY. An OPERABLED includes an RHR pump, a heat exchanger, valves, piping, instruments, a Is to ensure an OPERABLE flow path and to determine the RCS temperatur w path starts in one of the RCS hot legs and is returned to the RCS cold legs.

The LCO is modified by a Note that allows the required operating RHR loop to be removed from service for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period, provided no operations are permitted that would dilute the RCS boron concentration with coolant at boron concentrations less than required to meet the minimum boron concentration of LCO 3.9.1. Boron concentration reduction with coolant at boron concentrations less than required to assure the minimum required RCS boron concentration is maintained is prohibited because uniform concentration distribution cannot be ensured without forced circulation. This permits operations such as core mapping or alterations in the vicinity of the reactor vessel hot leg nozzles and RCS to RHR isolation valve testing. During this 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period, decay heat is removed by natural convection to the large mass of water in the refueling pool.

The acceptability of the LCO and the LCO Note is based on preventing core boiling in the event of the loss of RHR cooling. An evaluation (Ref. 2) was performed which demonstrated that there is adequate flow communication to provide sufficient decay heat removal capability and preclude core uncovery, thus preventing core damage, in the event of a loss of RHR cooling with the reactor cavity filled and the upper internals installed in the reactor vessel.

APPLICABILITY One RHR loop must be OPERABLE and in operation in MODE 6, with the water level >_23 ft above the top of the reactor vessel flange, to provide decay heat removal. The 23 ft water level was selected because it corresponds to the 23 ft requirement established for fuel movement in LCO 3.9.7, "Refueling Pool Water Level." Requirements for the RHR System in other MODES are covered by LCOs in Section 3.4, Reactor Coolant System (RCS), and Section 3.5, Emergency Core Cooling Systems (ECCS). RHR loop requirements in MODE 6 with the water level < 23 ft are located in LCO 3.9.6, "Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level."

Wolf Creek - Unit 1 B 3.9.5-2 Revision 32

Attachment IV to ET 14-0034 Page 20 of 24 RHR and Coolant Circulation - High Water Level B 3.9.5 BASES ACTIONS A.4 (continued)

The Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is reasonable, based on the low probability of the coolant boiling in that time.

SURVEILLANCE SR 3.9.5.1 REQUIREMENTS This Surveillance demonstrates that the RHR loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator in the control room for monitoring the RHR System.

REFERENCES 1. USAR, Section 5.4.7.

2. SAP-06-113, "Loss of RHR Analysis with the Refuel Cavity Flooded and Upper Internals Installed," November 16, 2006.

Wolf Creek - Unit I B 3.9.5-4 Revision 32

Attachment IVto ET 14-0034 Page 21 of 24 INSERT B 3.9.5-4 SR 3.9.5.2 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR loops and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.

Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The RHR System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR System is not rendered inoperable by the accumulated 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.

RHR System 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 31 day Frequency takes into consideration the gradual nature of gas accumulation in the RHR System piping and the procedural controls governing system operation.

Attachment IV to ET 14-0034 Page 22 of 24 RHR and Coolant Circulation - Low Water Level B 3.9.6 BASES LCO c. Indication of reactor coolant temperature.

oAn OPERABLE RHR loop consists of an RHR pump, a heat exchanger, mant o gas oystem ves, piping, instruments and controls to ensure an OPERABLE flow RH OrtaPntt syst pat to determine the RCS temperature. The flow path starts in one of the RC legs and is returned to the RCS cold legs. An OPERABLE RH must be capable of being realigned to provide an OPERABLE flow path.

When both RHR loops (or trains) are required to be OPERABLE, the associated Component Cooling Water (CCW) train is required to be OPERABLE. The heat sink for the CCW System is normally provided by the Service Water System or Essential Service Water (ESW) System, as determined by system availability. In MODES 5 and 6, one Diesel Generator (DG) is required to be OPERABLE per LCO 3.8.2, "AC Sources

- Shutdown." The same ESW train is required to be capable of performing its related support function(s) to support DG OPERABILITY.

However, a Service Water train can be utilized to support CCW/RHR OPERABILITY if the associated ESW train is not capable of performing its related support function(s).

APPLICABILITY Two RHR loops are required to be OPERABLE, and one RHR loop must be in operation in MODE 6, with the water level < 23 ft above the top of the reactor vessel flange, to provide decay heat removal.

Requirements for the RHR System in other MODES are covered by LCOs in Section 3.4, Reactor Coolant System (RCS), and Section 3.5, Emergency Core Cooling Systems (ECCS). RHR loop requirements in MODE 6 with the water level _> 23 ft are located in LCO 3.9.5, "Residual Heat Removal (RHR) and Coolant Circulation - High Water Level."

Since LCO 3.9.6 contains Required Actions with immediate Completion Times related to the restoration of the degraded decay heat removal function, it is not permitted to enter this LCO from either MODE 5 or from LCO 3.9.5, "RHR and Coolant Circulation - High Water Level,"

unless the requirements of LCO 3.9.6 are met. This precludes diminishing the backup decay heat removal capability when the RHR System is degraded.

ACTIONS A.1 and A.2 If less than the required number of RHR loops are OPERABLE, action shall be immediately initiated and continued until the RHR loop is restored to OPERABLE status and to operation in accordance with the LCO or until _> 23 ft of water level is established above the reactor Wolf Creek - Unit I B 3.9.6-2 Revision 63

Attachment IV to ET 14-0034 Page 23 of 24 RHR and Coolant Circulation - Low Water Level B 3.9.6 BASES SURVEILLANCE SR 3.9.6.1 REQUIREMENTS This Surveillance demonstrates that one RHR loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control,and alarm indications available to the operator for monitoring the RHR System in the control room.

SR 3.9.6.2 Verification that the required pump is OPERABLE ensures that an additional RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the required pump. The Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to

be acceptable by operating experience.

vv

1. USAR, Section 5.4.7.

2. Generic Letter No. 88-17, "Loss of Decay Heat Removal."

Wolf Creek - Unit 1 B 3.9.6-4 Revision 42 1

Attachment IVto ET 14-0034 Page 24 of 24 INSERT B 3.9.6-4 SR 3.9.6.3 RHR System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR loops and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.

Selection of RHR System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.

The RHR System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible locations exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR System is not rendered inoperable by the accumulated 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.

RHR System 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 31 day Frequency takes into consideration the gradual nature of gas accumulation in the RHR System piping and the procedural controls governing system operation.

v t e Letter Sequence Request
TAC:MF5280, Generic Letter 2008-01, Managing Gas Accumulation (Approved, Closed)
Initiation Request, Request Acceptance Administration Questions 9 February 2015 10 February 2015 27 March 2015 Answers 18 March 2015 Results Approval Other:
MONTHYEAR2015-02-09 [Table View]

ET 14-0034, Application to Revise Technical Specifications to Adopt TSTF-523, Revision 2, Generic Letter 2008-01, Managing Gas Accumulation, Using the Consolidated Line Item Improvement Process

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ET 14-0034, Application to Revise Technical Specifications to Adopt TSTF-523, Revision 2, Generic Letter 2008-01, Managing Gas Accumulation, Using the Consolidated Line Item Improvement Process

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3.0 REGULATORY ANALYSIS

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