Text

Revision to Technical Specification 3.3.2, Engineered Safety Feature Actuation System (ESFAS) Instrumentation.
	ML082350072
Person / Time
Site:	Wolf Creek
Issue date:	08/14/2008
From:	Garrett T; Wolf Creek
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	ET 08-0041
	Download: ML082350072 (59)
	v • d • e

W0LF CREEK NUCLEAR OPERATING CORPORATION Terry J. Garrett August 14, 2008 Vice President, Engineering ET 08-0041 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555

Subject:

Docket No. 50-482: Revision to Technical Specification 3.3.2, "Engineered Safety Feature Actuation System (ESFAS)

Instrumentation" Gentlemen:

Pursuant to 10 CFR 50.90, Wolf Creek Nuclear Operating Corporation (WCNOC) hereby requests an amendment to Operating License NPF-42 for the Wolf Creek Generating Station (WCGS) to incorporate proposed changes into the WCGS Technical Specifications (TS).

The proposed changes will revise TS 3.3.2, "Engineered Safety Feature Actuation -System (ESFAS)" to extend the Surveillance Frequency on selected ESFAS slave relays from 92 days to 18 months. Justification for extending the slave relay Surveillance Frequency is based on information contained in the Westinghouse Electric Corporation reports WCAP-13878-P-A, Revision 2 (proprietary version) and WCAP-14117-NP-A, Revision 2 (nonproprietary version),

"Reliability Assessment of Potter & Brumfield MDR Series Relays," dated August 2000.

Attachment I through IV provide the Evaluation, Markup of TSs, Retyped TS pages, and proposed TS Bases changes, respectively, in support of this amendment request. Attachment IV, proposed changes to the TS 3.3.2 Bases, is provided 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. Attachment V provides a List of Regulatory Commitments made by WCNOC in this submittal.

It has been determined that this amendment application does not involve a significant hazard consideration as determined per 10 CFR 50.92. The amendment application was reviewed by the WCNOC Plant Safety Review Committee. In accordance with 10 CFR 50.91, a copy of this application is being provided to the designated Kansas State official.

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

ET 08-0041 Page 2 of 3 WCNOC requests approval of this proposed amendment by July 31, 2009. Once approved, the amendment will be implemented within 90 days.

If you have any questions concerning this matter, please contact me at (620) 364-4084, or Mr.

Richard D. Flannigan at (620) 364-4117.

Sincerely,

rHJ'. Garrett TJG/rlt Attachments: Evaluation IV Markup of Technical Specification Pages II Retyped Technical Specification Pages IV Proposed TS Bases Changes (for information only)

V List of Regulatory Commitments cc: E. E. Collins (NRC), w/a T. A. Conley (KDHE), w/a V. G. Gaddy (NRC), w/a B. K. Singal (NRC), w/a Senior Resident Inspector (NRC), w/a

ET 08-0041 Page 3 of 3 STATE OF KANSAS )

SS COUNTY OF COFFEY )

Terry J. Garrett, 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_ e Ter .o Garrett Vice President Engineering SUBSCRIBED and sworn to before me this /N/i/day off/ag, 2008.

] IO RHONDA L.TIEMEYER to FICIAQ oar ubi

..SEAL :.,. MY COMMISSION EXPIRES January 11, 2010 Notary Public Expiration Date ,/19///,')/L9 U v

Attachment I to ET 08-0041 Page 1 of 9 EVALUATION 1.0

SUMMARY

DESCRIPTION 2.0 DETAILED DESCRIPTION

3.0 TECHNICAL EVALUATION

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements 4.2 Precedent 4.3 Significant Hazards Consideration 4.4 Conclusions

5.0 ENVIRONMENTAL CONSIDERATION

6.0 REFERENCES

Attachment I to ET 08-0041 Page 2 of 9 EVALUATION 1.0

SUMMARY

DESCRIPTION The amendment application involves changes to the Wolf Creek Generating Station (WCGS) Technical Specifications (TS) to revise TS 3.3.2, "Engineered Safety Feature Actuation System (ESFAS)" to extend the Surveillance Frequency on selected ESFAS slave relay from 92 days to 18 months. Justification for extending the slave relay Surveillance Frequency is based on information contained in the Westinghouse Electric Corporation reports WCAP-13878-P-A, Revision 2 (Reference 6.1) and WCAP-14117-NP-A, Revision 2 (nonproprietary version), "Reliability Assessment of Potter & Brumfield MDR Series Relays," dated August 2000.

2.0 DETAILED DESCRIPTION WCAP-13878-P-A, Revision 2, provides the technical basis and methodology for revising the Surveillance Frequency for the Potter & Brumfield MDR series relays identified in the WCAP and used in engineered safety feature (ESF) applications. Slave relay testing has the potential to cause inadvertent ESF actuation and/or reactor trip.

Extending the Surveillance Frequency reduces the number of tests performed on the relays, thus reducing the potential for unnecessary ESF actuation or reactor trip.

Proposed changes to the TSs are as follows:

Table of Contents is revised to reflect repagination as a result of the proposed change.

Surveillance Requirement (SR) 3.3.2.6 is revised by deleting the Note to the SR and changing the Frequency from 92 days to 18 months.

SR 3.3.2.13 and SR 3.3.2.14 are deleted. The deletion of these two SRs result in deleting the "continued" on page 3.3-30 and placing a double line in the table to indicate the end of the Surveillance Requirements table.

Table 3.3.2-1, "Engineered Safety Feature Actuation System Instrumentation," is revised as follows:

Function 1.b., Safety Injection - Automatic Actuation Logic and Actuation Relays

- SR 3.3.2.13 is deleted as a required Surveillance.

" Function 3.a.(2), Containment Isolation - Phase A Isolation - Automatic Actuation Logic and Actuation Relays - SR 3.3.2.13 is deleted as a required Surveillance.

" Function 5.a., Turbine Trip and Feedwater Isolation - Automatic Logic and Actuation Relays (SSPS) - SR 3.3.2.14 is deleted as a required Surveillance.

Attachment I to ET 08-0041 Page 3 of 9

Function 7.a., Automatic Switchover to Containment Sump - Automatic Logic and Actuation Relays - SR 3.3.2.13 is revised to SR 3.3.2.6.

3.0 TECHNICAL EVALUATION

3.1 System Description The Solid State Protection System (SSPS) initiates the proper unit shutdown or engineered safety feature (ESF) actuation in accordance with the defined logic and based on the bistable outputs from the signal process control and protection system.

The SSPS equipment is used for the decision logic processing of outputs from the signal processing equipment bistables. To meet the redundancy requirements, two trains of SSPS, each performing the same functions, are provided. If one train is taken out of service for maintenance or test purposes, the second train will provide ESF actuation for the unit. If both trains are taken out of service or placed in test, a reactor trip will result.

The SSPS performs the decision logic for most ESF equipment actuation; generates the electrical output signals that initiate the required actuation; and provides the status, permissive, and- annunciator output signals to the control room.

The bistable outputs from the signal processing equipment are sensed by the SSPS equipment and combined into logic matrices that represent combinations indicative of various transients. If a required logic matrix combination is completed, the system will send actuation signals via master and slave relays to those components whose aggregate function best serves to alleviate the condition and restore the unit to a safe condition.

3.2 Relay Testing The actuation of ESF components is accomplished through master and slave relays.

The SSPS energizes the master relays appropriate for the condition of the unit. Each master relay then energizes one or more slave relays, which then cause actuation of the end devices. The master and slave relays are routinely tested to ensure operation. The test of the master relays energizes the relay, which then operates the contacts and applies a low voltage to the associated slave relays. The low voltage is not sufficient to actuate the slave relays but only demonstrates signal path continuity. The SLAVE RELAY TEST actuates the devices if their operation will not interfere with continued unit operation.

Surveillance testing can identify relay failures before the relay is required to perform its intended function. However, relay testing has the potential to cause inadvertent ESF actuation and/or reactor trip. Extending the Surveillance Frequency reduces the number of surveillances performed on the relays, thus reducing the potential for unnecessary ESF actuations.

Nuclear Regulatory Commission (NRC) Generic Letter 93-05, "Line Item Technical Specification Improvements to Reduce Surveillance Requirements for Testing During

Attachment I to ET 08-0041 Page 4 of 9 Power Operation," (Reference 6.2) documents the results of a study of Surveillance testing required by TSs. The studies found that, while some testing at power is essential to verify equipment and system OPERABILITY, reducing the amount of testing at power will improve safety, decrease equipment degradation, and relieve personnel burden. Extending the Surveillance Frequency for slave relay testing is consistent with the recommendations of Generic Letter 93-05.

3.3 Technical Analysis This application to extend the slave relay test intervals is based on information contained in WCAP-13878-P-A, Revision 2, "Reliability Assessment of Potter &

Brumfield MDR Series Relays," dated August 2000. WCAP-13878 documents a reliability assessment by Westinghouse to establish a basis for determining the reliability of Potter & Brumfield MDR series relays. A particular objective was to demonstrate that Surveillance testing of the relays at 18-month intervals would not adversely affect the reliability of the SSPS.

WCAP-13878 contains the technical basis and methodology for extending slave relay test requirements for Potter & Brumfield MDR slave relays. Following review of WCAP-13878, the NRC issued safety evaluations dated May 31, 1996, and July 12, 2000, which state the conclusion that the failure data and analysis provided for Potter &

Brumfield MDR slave relays used in SSPS applications support the proposed test interval extension. Based on the conclusions of WCAP-13878, slave relay testing of Potter & Brumfield MDR relays on a refueling frequency (i.e., 18 months) is adequate to confirm reliability and continuing OPERABILITY of the slave relays. The WCAP specifies Potter & Brumfield MDR slave relay models 4103-1 and 4121-1.

For plant specific approval, the NRC specified in the May 31, 1996 safety evaluation that the following information be provided:

1. Confirm the applicability of the WCAP-13878, Revision I analyses for their plant.

Potter & Brumfield MDR slave relays models 4103-1 and 4121-1 are used in WCGS ESFAS applications that require testing per TSs. These relays are bounded by WCAP-13878-P-A and have environmental conditions similar to those in the WCAP. WCGS slave relays are normally de-energized, with the exception of one relay which is normally energized (K637).

2. Ensure that their procurement program for P&B MDR relays is adequate for detecting the types of failures that are discussed in References 9, 10, 11 and 12.

WCNOC has determined that the procurement program for Potter & Brumfield MDR relays used in TS applications is adequate for detecting the types of failures discussed in the NRC safety evaluation. Applicability of the referenced failure type to WCGS are as follows:

0 Relays in normally energized applications.

All normally energized relays have been replace by post-1992 relays.

Attachment I to ET 08-0041 Page 5 of 9

Substandard or refurbished relays.

Potter & Brumfield MDR relays currently installed in the plant have met application requirements. Should a relay require replacement, WCNOC currently procures qualified replacement relays from Westinghouse.

Additionally, the MDR relays manufacturer (Tyco Electronics Corporation) is surveyed periodically under the Nuclear Utility Procurement Issues Committee joint survey program. The survey ensures that standards of control are met in design, procurement, materials, manufacturing process, inspection, testing, and measurement and test equipment.

3. Ensure that all pre-1992 P&B MDR relays which are used in either normally energized or a 20% duty cycle have been removed from ESFAS applications.

All normally energized or 20% duty cycle relays have been replaced with post-1992 relays.

4. Ensure that the contact loading analysis for P&B MDR relays has been performed to determine the acceptability of these relays.

A technical review (TSA 20401-009) of the adequacy of contact loading of MDR relays which are subject to the TS slave relay test Surveillance has been performed. This review concluded that the slave relay contacts are adequate for their applications.

5. Re-evaluate the adequacy of the extended surveillance interval if two or more P&B MDR ESFAS subgroup relays fail in a 12 month period.

To support implementation of the extended Surveillance Frequency, the Maintenance Rule program provides for monitoring performance results of the MDR slave relays. The Maintenance Rule Program implements the requirements of 10 CFR 50.65 and provides instructions for initiation, analysis, retrieval, trending, and periodic reporting of data relative performance indicators of plant systems and components. The program includes guidance for trending and reporting of repetitive preventable failures of functions that are within the scope of the Maintenance Rule. It also includes performance of cause determinations for failures to meet performance criteria and for repetitive failures.

The functional failure guidance for ESFAS specifies that a functional failure is any failure that results in a complete loss of train actuation. The performance criteria for ESFAS is less than or equal to one functional failure of a train of actuation per 18 months. The failure of a MDR slave relay would be considered a functional failure and would result in an evaluation of the failure including the adequacy of the extended surveillance interval.

Attachment I to ET 08-0041 Page 6 of 9

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements/Criteria The regulatory basis for the Technical Specification surveillance requirements is to ensure that accident conditions are sensed and operation of systems and components important to safety is initiated in order to protect against violating core design limits, challenging the Reactor Coolant System boundary, and to mitigate the consequences of accidents.

GDC 20, "Protection system functions," requires that the protection system be designed to initiate the operation of systems and components important to safety.

GDC 21, "Protection system reliability and testability," requires that the protection system shall be designed for high functional reliability and inservice testability commensurate with the safety functions to be performed. GDC 21 also requires that the protection system be designed so as to permit functional testing during reactor operation in order to determine and identify failures and losses of redundancy.

GDC 29, "Protection against anticipated operational occurrences," requires that protection systems be designed to assure an extremely high probability of accomplishing their functions in the event of anticipated operational occurrences.

10 CFR 50.55a(h) requires that protection systems meet the requirements set forth in IEEE 279, "Criteria for Protection Systems for Nuclear Power Generating Stations."

Section 4.10 of IEEE 279-1971 requires that capability be provided for testing and calibrating protection system equipment and indicates when such equipment must be tested during reactor operation.

The requirements of GDC 20, 21, and 29 continue to be met because the change being proposed will not affect the design capability, function, operation, or method of testing the Solid State Protection System or associated slave relays. The requirements of IEEE 279 continue to be satisfied because the only change being proposed is a reduction in the frequency of required testing; the frequency of required testing is not specified in IEEE 279.

4.2 Precedent Amendment No. 224 and Amendment No. 219 were issued on May 24, 2005, for the Catawaba Nuclear Station, Units 1 and 2. These amendments revise the Surveillance Frequency from 92 days to 18 months for certain Westinghouse Type AR slave relays and for certain Potter & Brumfield MDR series slave relays. The primary difference the Catawaba Nuclear Station amendments and this application is that WCNOC is not requesting approval for Westinghouse Type AR slave relays. WCGS does not use Westinghouse Type AR slave relays in any ESF application. (ADAMS Accession Number ML051020543)

Attachment I to ET 08-0041 Page 7 of 9 Amendment No. 152 and Amendment No. 140 were issued on May 19, 2003 for the South Texas Project, Units 1 and 2. The amendments extend the interval between slave relay tests in the ESFAS instrumentation from 3 months to 18 months. The primary difference between the South Texas Project amendments and this application is the South Texas Project included Model 4156 relays, which were'not evaluated in WCSP-13878, in their application. WCNOC does not use Model 4156 relays in any ESF application. (ADAMS Accession Number ML0314110592) 4.3 Significant Hazards Consideration This amendment request involves changes to the Wolf Creek Generating Station (WCGS) Technical Specifications (TS) to revise TS 3.3.2, "Engineered Safety Feature Actuation System (ESFAS)" to extend the Surveillance Frequency on selected ESFAS slave relay from 92 days to 18 months. Justification for extending the slave relay Surveillance Frequency is based on information contained in the Westinghouse Electric Corporation reports WCAP-13878-P-A, Revision 2 (Reference 6.1) and WCAP-14117-NP-A, Revision 2 (nonproprietary version), "Reliability Assessment, of Potter & Brumfield MDR Series Relays," dated August 2000.

WCNOC has evaluated whether or not a significant hazards consideration is involved with the proposed amendment by focusing on the three standards set forth in 10 CFR 50.92, Issuance of amendment, as discussed below:

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

Response: No The proposed change will not result in a condition where the design, material, and construction standards that were applicable prior to the change are altered. The same Engineered Safety Feature Actuation System (ESFAS) instrumentation will be used and the same ESFAS system reliability is expected. The same ESFAS instrumentation will be used and the same ESFAS reliability is expected. Overall protection system performance will remain within the bounds of the previously performed accident analyses since there are no design changes. There will be no changes to any design or operating limits.

The proposed changes will not change accident initiators or precursors assumed or postulated in the Updated Safety Analysis Report (USAR) described accident analyses, nor will they alter the design assumptions, conditions, and configuration of the facility or the manner in which the plant is operated and maintained. The proposed changes will not alter or prevent the ability of structures, systems, and components (SSCs) from performing their intended functions to mitigate the consequences of an initiating event within the assumed acceptance limits.

The proposed changes do not physically alter safety related systems, nor do they affect the way in which safety related systems perform their functions. All accident analysis acceptance criteria will continue to be met with the proposed changes. The

Attachment I to ET 08-0041 Page 8 of 9 proposed changes will not affect the source term, containment isolation, or radiological release assumptions used in evaluating the radiological consequences of an accident previously evaluated. The proposed changes will not alter any assumptions or change any mitigation actions in the radiological consequence evaluations in the USAR. The applicable radiological dose acceptance criteria will continue to be met.

Based on the above considerations, the proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated.

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

Response: No There are no proposed design changes, nor are there any changes in the method by which any safety-related plant SSC performs its specified safety function. Changing the interval for periodically verifying the ESFAS slave relays will not create any new accident initiators or scenarios. The proposed changes will not affect the normal method of plant operation or change any operating parameters. No equipment performance requirements will be affected. The proposed changes will not alter any assumptions made in the safety analyses.

No new accident scenarios, transient precursors, failure mechanisms, or limiting single failures will be introduced as a result of this amendment. There will be no adverse effect or challenges imposed on any safety-related system as a result of this amendment. The proposed amendment will not alter the design or performance of the 7300 Process Protection System, Nuclear Instrumentation System, or Solid State Protection System used in the plant protection systems.

Therefore, the proposed changes do not create the possibility of a new or different accident from any accident previously evaluated.

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

Response: No The proposed change will not affect the total ESFAS response assumed in the safety analysis because the reliability of the slave relays will not be significantly affected by the increased surveillance interval. The relays have demonstrated a high reliability and insensitivity to short term wear and aging effects. The overall reliability, redundancy, and diversity assumed available for the protection and mitigation of accident and transient conditions is unaffected by this proposed change.

There will be no effect on those plant systems necessary to assure the accomplishment of protection functions. There will be no impact on the overpower limit, departure from nucleate boiling ratio (DNBR) limits, heat flux hot channel factor

Attachment I to ET 08-0041 Page 9 of 9 (FQ), nuclear enthalpy rise hot channel factor (FAH), loss of coolant accident peak cladding temperature (LOCA PCT), peak local power density, or any other margin of safety. The applicable radiological dose consequence acceptance criteria for design-basis transients and accidents will continue to be met.

None of the acceptance criteria for any accident analysis will be changed.

Therefore, the proposed changes do not involve a significant reduction in a margin of safety.

The proposed amendment 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. In conclusion, based on the considerations discussed above, 1) there is a 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.

5.0 ENVIRONMENTAL CONSIDERATION

WCNOC has evaluated the proposed change and has determined that the change does not involve (i) a significant hazards consideration, (ii) a significant change in the types of or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure.

Accordingly, the proposed change meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), an environmental assessment of the proposed change is not required.

6.0 REFERENCES

6.1 WCAP-1 3878-P-A, Revision 2 "Reliability Assessment of Potter & Brumfield MDR Series Relays," dated August 2000.

6.2 NRC Generic Letter 93-05, "Line Item Technical Specification Improvements to Reduce Surveillance Requirements for Testing During Power Operation,"

September 27, 1993.

Attachment II to ET 08-0041 Page 1 of 10 Markup of Technical Specification Pages

Attachment II to ET 08-0041 Page 2 of 10 TABLE OF CONTENTS 1.0 USE AND APPLICATION ................................................................................. 1.1-1 1 .1 Defin itio ns ................................................................................................. 1 .1-1 1.2 Logical C onnectors .................................................................................. 1.2-1 1.3 C om pletion T imes ..................................................................................... 1.3-1 1.4 F req ue ncy ................................................................................................. 1.4 -1 2.0 SA FETY LIM ITS (S Ls) ...................................................................................... 2.0-1 2 .1 S Ls .................................................................................................... 2 .0 -1 2 .2 S L V iolatio ns ............................................................................................ 2 .0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ............... 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ............................... 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS ........................................................ 3.1-1 3.1.1 SHUTDOWN MARGIN (SDM) ......................................................... 3.1-1 3.1.2 C ore R eactivity .................................................................................. 3.1-2 3.1.3 Moderator Temperature Coefficient (MTC) ...................................... 3.1-4 3.1.4 Rod Group Alignment Limits ............................................................. 3.1-7 3.1.5 Shutdown Bank Insertion Limits ........................... ...................... 3.1-11 3.1.6 Control Bank Insertion Limits..: ......................................................... 3.1-13 3.1.7 Rod Position Indication .................................................... ................. 3.1-16 3.1.8 PHYSICS TESTS Exceptions - MODE 2 ........................................ 3.1-19 3.2 POWER DISTRIBUTION LIMITS ............................................................. 3.2-1 3.2.1 Heat Flux Hot Channel Factor (FQ(Z))

(FQ Methodology) ........................................................................ 3.2-1 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FH) .................. 3.2-6 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC) Methodology) .................................................... 3.2-9 3.2.4 QUADRANT POWER TILT RATIO (QPTR) ..................................... 3.2-10 3.3 INST R UME NTAT IO N ................................................................................ 3.3-1 3.3.1 Reactor Trip System (RTS) Instrumentation .................................... 3.3-1 3.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrum entatio n ........................................................................... 3 .3 - 7(,::

3.3.3 Post Accident Monitoring (PAM) Instrumentation ............................. 3.3- _

3.3.4 Remote Shutdown System ............................................................... 3.3 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation ....................................................... 3 Wolf Creek - Unit 1 Amendment No. 42-, 173

Attachment II to ET 08-0041 Page 3 of 10 TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.6 Containment Purge Isolation Instrumentation ..................................

3.3.7 Control Room Emergency Ventilation System (CREVS)

Actuation Instrumentation ..................................................... 3-L0) 3-..-

3.3.8 Emergency Exhaust System (EES) Actuation Instrumentation .................................. .3 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 I and 2 .......................................................... 3.4-8 3.4.5 RCS Loops - MO DE 3 ...................................................................... 3.4-9 3.4.6 RCS Loops - MO DE 4.. ..................................................................... 3.4-12 3.4.7 RCS Loops - MODE 5, Loops Filled ................................................. 3.4-14 3.4.8 RCS Loops - MODE 5, Loops Not Filled .......................................... 3.4-17 3.4 .9 P ressurizer ........................................................................................ 3.4-19 3.4.10 Pressurizer Safety Valves ................................................................. 3.4-21 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) ....................... 3.4-23 3.4.12 Low Temperature Overpressure Protection (LTOP) System ........... 3.4-26 3.4.13 RCS Operational LEAKAGE ............................................................. 3.4-31 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage .................................. 3.4-33 3.4.15 RCS Leakage Detection Instrumentation ......................................... 3.4-37 3.4.16 RC S S pecific Activity ......................................................................... 3.4-41 3.4.17 Steam Generator (SG) Tube Integrity ................................................ 3.4-43 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) .............................. 3.5-1 3.5.1 Accum ulators .................................................................................... 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 Seal Injection Flow ............................................................................ 3.5-10 3.6 CONTAINMENT SYSTEMS ..................................................................... 3.6-1 3 .6 .1 C ontainm ent ..................................................................................... 3.6-1 3.6.2 Containm ent 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 .................................. 3.6-19 Wolf Creek - Unit 1 ii Amendment No. 123, 131, 157, 164,167 170

Attachment IIto ET 08-0041 Page 4 of 10 ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued' SURVEILLANCE SR 3.3.2.3 --------------- NOTE ---------------

The continuity check may be excluded.

Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.2.4 Perform MASTER RELAY TEST.

SR 3.3.2.5 Perform COT.

SR 3.3.2.6 Perform SLAVE RELAY TEST.

SR 3.3.2.7 ---------------- NOTE ---------------

Verification of relay setpoints not required.

Perform TADOT. 18 months (continued)

Wolf Creek - Unit 1 3.3-29 Amendment No. 123,131, 156

Attachment II to ET 08-0041 Page 5 of 10 ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.8 -------------------- NOTE-.---------------

Verification of setpoint not required for manual initiation functions.

Perform TADOT. 18 months SR 3.3.2.9 -------------------- NOTE ----------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 18 months SR 3.3.2.10 ------------------- NOTE ----------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SG pressure is

> 900 psig.

Verify ESF RESPONSE TIMES are within limits. 18 months on a STAGGERED TEST BASIS SR 3.3.2.11 ------------------- NOTE ----------------

Verification of setpoint not required.

Perform TADOT. 18 months SR 3.3.2.12 Perform COT. 31 days fx oCo-~e m

lb av d .. ~ veickc&lo Wolf Creek - Unit 1 3.3-30 Amendment No. 4-23, 131 I

Attachment II to ET 08-0041 Page 6 of 10 ESFAS Instrumentation 3.3.2 Wolf Creek - Unit 1 3.3-31 Amendment No. 123

Attachment II to ET 08-0041 Page 7 of 10 ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (a)

1. Safety Injection

a. Manual Initiation 1,2,3,4 2 B SR 3.3.2.8 NA

b. Automatic Actuation 1,2,3,4 2 trains C SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

c. Containment Pressure - 1,2,3 3 D SR 3.3.2.1 <4.5 psig High 1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

d. Pressurizer Pressure - 4 D SR 3.3.2.1 Žl 820 psig I Low SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

e. Steam Line Pressure 1,2 ,3 (b) 3 per steam D SR 3.3.2.1 Ž>571 psig(c)

Low line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

2. Containment Spray

a. Manual Initiation 1,2,3,4 2 per train, B SR 3.3.2.8 NA 2 trains

b. Automatic Actuation 1,2,3,4 2 trains C SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

c. Containment Pressure 1,2,3 4 E SR 3.3.2.1 *28.3 psig High-3 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the Limiting Safety System Setting. See the Bases for the Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) interlock and below P-11 unless the Function is blocked.

(c) Time constants used in the lead/lag controller are t, > 50 seconds and t2 < 5 seconds.

Wolf Creek - Unit 1 3.3-32 Amendment No. 4-2-3, 140

Attachment II to ET 08-0041 Page 8 of 10 ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (a)

3. Containment Isolation

a. Phase A Isolation (1) Manual Initiation 1,2,3,4 2 B SR 3.3.2.8 NA (2) Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR3.3,2.6 Relays (3) Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

b. Phase B Isolation (1) Manual Initiation 1,2,3,4 2 per train, B SR 3.3.2.8 NA 2 trains (2) Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (3) Containment 1,2,3 4 E SR 3.3.2.1 *28.3 psig Pressure - SR 3.3.2.5 High 3 SR 3.3.2.9 SR 3.3.2.10

4. Steam Line Isolation

a. Manual Initiation 1,2(i), 3 (i) 2 F SR 3.3.2.8 NA

b. Automatic Actuation 1,2(i), 3 (i) 2 trains G SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays (SSPS) SR 3.3.2.6

c. Automatic Actuation 1,2(i), 3 (i) 2 trains G SR 3.3.2.6 NA Logic (MSFIS)

d. Containment Pressure 1,2(i), 3 (i) 3 D SR 3.3.2.1 !5 18.3 psig

- High 2 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the Limiting Safety System Setting. See the Bases for the Trip Setpoints.

(i) Except when all MSIVs are closed.

Wolf Creek - Unit 1 3.3-33 Amendment No. --2-, 175

Attachment II to ET 08-0041 Page 9 of 10 ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (a)

4. Steam Line Isolation (continued)

e. Steam Line Pressure (1) Low 1,2 (i),3 (b)(i) 3 per steam D SR 3.3.2.1 >571 psig(c) line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (2) Negative Rate - 3 (g)(i) 3 per steam D SR 3.3.2.1 _1 2 5 (h) psi High line- SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

5. Turbine Trip and Feedwater Isolation

a. Automatic Actuation 1,2(),3(J) 2 trains G SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays (SSPS) SR 3.3.2.6

b. Automatic Actuation 1 ,2 (k), 3 (k) 2 trains G SR 3.3.2.6 NA Logic (MSFIS)

c. SG Water Level -High 12(J) 4 per SG I SR 3.3.2.1 !< 79.7% of High (P-14) SR 3.3.2.5 Narrow Range SR 3.3.2.9 Instrument Span SR 3.3.2.10

d. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

(continued)

(a) The Allowable Value defines theLimiting Safety System Setting. See the Bases for the Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-11 unless the Function is blocked.

(c) Time constants used in the lead/lag controller are t, ->50 seconds and t 2 < 5 seconds.

(g) Below the P-11 (Pressurizer Pressure) Interlock; however, may be blocked below P-11 when safety injection on low steam line pressure is not blocked.

(h) Time constant utilized in the rate/lag controller is >Ž50 seconds.

(i) Except when all MSIVs are closed.

(j) Except when all MFIVs are closed and de-activated; and all MFRVs are closed and de-activated or closed and isolated by a closed manual valve; and all MFRV bypass valves are closed and de-activated, or closed and isolated by a closed manual valve, or isolated by two closed manual valves.

(k) Except when all MFIVs are closed and de-activated.

Wolf Creek - Unit 1 3.3-34 Amendment No. 123, 132., 475, 177

I, Attachment II to ET 08-0041 Page 10 of 10 ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

7. Automatic Switchover to Containment Sump

a. Automatic Actuation 1,2,3,4 2 trains C SR 3.3.2.2 NA Logic and Actuation SIR 3.3.2.4 Relays

b. Refueling Water 1,2,3,4 4 K SR 3.3.2.1 > 35.5% of Storage Tank SR 3.3.2.5 instrument span (RWST) Level - Low SR 3.3.2.9 Low SR 3.3.2.10 Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Safety Injection B. ESFAS Interlocks

a. Reactor Trip, P-4 1,2,3 2 per train, F SR 3.3.2.11 NA 2 trains

b. Pressurizer Pressure, 1,2,3 3 L SR 3.3.2.5 < 1979 psig P-11 SR 3.3.2.9 (a) The Allowable Value defines the Limiting Safety System Settings. See the Bases for the Trip Setpoints.

Wolf Creek -.Unit 1 3.3-36 Amendment No. 123, !26, 132

Attachment III to ET 08-0041 Page 1 of 16 Retyped Technical Specification Pages

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.3 ----------------------- NOTE -----------------

The continuity check may be excluded.

Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.2.4 Perform MASTER RELAY TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.2.5 Perform COT. 184 days SR 3.3.2.6 Perform SLAVE RELAY TEST. 18 months SR 3.3.2.7 ------------------------ NOTE- ----------------

Verification of relay setpoints not required.

Perform TADOT. 18 months (continued)

Wolf Creek - Unit 1 3.3-29 Amendment No. 12.,o , 1-.456,

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.8 -- ----------------- NOTE ----------------

Verification of setpoint not required for manual initiation functions.

Perform TADOT. 18 months SR 3.3.2.9 --------------------- NOTE-----------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 18 months SR 3.3.2.10 -------------------- NOTE ----------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SG pressure is

_Ž 900 psig.

Verify ESF RESPONSE TIMES are within limits. 18 months on a STAGGERED TEST BASIS SR 3.3.2.11 -------------------- NOTE ----------------

Verification of setpoint not required.

Perform TADOT. 18 months SR 3.3.2.12 Perform COT. 31 days Wolf Creek - Unit 1 3.3-30 Amendment No. 123,131, 1

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (a) 1 Safety Injection

a. Manual Initiation 1,2,3,4 2 B SR 3.3.2.8 NA

b. Automatic Actuation 1,2,3,4 2 trains C SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

c. Containment Pressure - 1,2,3 3 D SR 3.3.2.1 *4.5 psig High 1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

d. Pressurizer Pressure - 4 D SR 3.3.2.1 Ž1820 psig Low SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 D SR 3.3.2.1

e. Steam Line Pressure 1,2 ,3 (b) 3 per steam SR 3.3.2.5 Ž 571 psig(c)

Low line SR 3.3.2.9 SR 3.3.2.10

2. Containment Spray SSR 3.3.2.8

a. Manual Initiation 1,2,3,4 2 per train, NA 2 trains C SR 3.3.2.2

b. Automatic Actuation Logic and Actuation 1,2,3,4 2 trains SR 3.3.2.4 NA SR 3.3.2.6 Relays E SR 3.3.2.1

c. Containment Pressure 1,2,3 4 SR 3.3.2.5 -*28.3 psig High - 3 SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the Limiting Safety System Setting. See the Bases for the Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) interlock and below P-11 unless the Function is blocked.

(c) Time constants used in the lead/lag controller are t, >-50 seconds and t2 -<5 seconds.

Wolf Creek - Unit 1 3.3-31 Amendment No. 123,-140,

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (a)

3. Containment Isolation

a. Phase A Isolation (1) Manual Initiation 1,2,3,4 B SR 3.3.2.8 NA (2) Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (3) Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

b. Phase B Isolation (1) Manual Initiation 1,2,3,4 2 per train, B SR 3.3.2.8 NA 2 trains (2) Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (3) Containment 1,2,3 4 E SR 3.3.2.1 < 28.3 psig Pressure - SR 3.3.2.5 High 3 SR 3.3.2.9 SR 3.3.2.10

4. Steam Line Isolation

a. Manual Initiation 12(i), 3 (i) 2 F SR 3.3.2.8 NA

b. Automatic Actuation 1,2(i), 3 (i) 2 trains G SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays (SSPS) SR 3.3.2.6

c. Automatic Actuation 1,2(i), 3 (i) 2 trains G SR 3.3.2.6 NA Logic (MSFIS)

d. Containment Pressure 1,2(i), 3 (i) 3 D SR 3.3.2.1 <18.3 psig

- High 2 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the Limiting Safety System Setting. See the Bases for the Trip Setpoints.

(i) Except when all MSIVs are closed.

Wolf Creek - Unit 1 3.3-32 Amendment No. 123,!75,

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE

.FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (a)

4. Steam Line Isolation (continued)

e. Steam Line Pressure (1) Low 1,2 (i),3 (b)(i) 3 per steam D SR 3.3.2.1 2!571 psig(c) line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (2) Negative Rate - 3 (g)(i) 3 per steam D SR 3.3.2.1 < 125 (h) psi High line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

5. Turbine Trip and Feedwater Isolation

a. Automatic Actuation 1,2(J),3(J) 2 trains G SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays (SSPS) SR 3.3.2.6 1,2(k),3(k)

b. Automatic Actuation 2 trains G SR 3.3.2.6 NA Logic (MSFIS)

c. SG Water Level -High 1,20) 4 per SG SR 3.3.2.1

79.7% of High (P-14) SR 3.3.2.5 Narrow Range SR 3.3.2.9 Instrument Span SR 3.3.2.10

d. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

(continued)

(a) The Allowable Value defines the Limiting Safety System Setting. See the Bases for the Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-11 unless the Function is blocked.

(c) Time constants used in the lead/lag controller are ti ->50 seconds and t2 <- 5 seconds.

(g) Below the P-11 (Pressurizer Pressure) Interlock; however, may be blocked below P-11 when safety injection on low steam line pressure is not blocked.

(h) Time constant utilized in the rate/lag controller is >_50 seconds.

(i) Except when all MSIVs are closed.

(j) Except when all MFIVs are closed and de-activated; and all MFRVs are closed and de-activated or closed and isolated by a closed manual valve; and all MFRV bypass valves are closed and de-activated, or closed and isolated by a closed manual valve, or isolated by two closed manual valves.

(k) Except when all MFIVs are closed and de-activated.

Wolf Creek - Unit 1 3.3-33 Amendment No. 123, 132, 175, 177,

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (a)

6. Auxiliary Feedwater

a. Manual Initiation 1,2,3 1 per pump 0 SR 3.3.2.8 NA

b. Automatic Actuation 1,2,3 2 trains G SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays (Solid State SR 3.3.2.6 Protection System)

c. Automatic Actuation 1,2,3 2 trains N SR 3.3.2.3 NA Logic and Actuation Relays (Balance of Plant ESFAS)

d. SG Water Level Low - 1,2,3 4 per SG D SR 3.3.2.1 Ž_22.3% of Low SR 3.3.2.5 Narrow Range SR 3.3.2.9 Instrument Span SR 3.3.2.10

e. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

f. Loss of Offsite Power 1,2,3 2 trains P SR 3.3.2.7 NA SR 3.3.2.10

g. Trip of all Main 2 per pump J SR 3.3.2.8 NA Feedwater Pumps

h. Auxiliary Feedwater 1,2,3 3 M SIR 3.3.2.1

Ž20.53 psia Pump Suction SR 3.3.2.9 Transfer on Suction SR 3.3.2.10 Pressure - Low SR 3.3.2.12 (continued)

(a) The Allowable Value defines the Limiting Safety System Setting. See the Bases for the Trip Setpoints.

Wolf Creek - Unit 1 3.3-34 Amendment No. 1-2.3,-13",

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 5)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

7. Automatic Switchover to Containment Sump

a. Automatic Actuation 1,2,3,4 2 trains C SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

b. Refueling Water 1,2,3,4 4 K SR 3.3.2.1 _35.5% of Storage Tank (RWST) SR 3.3.2.5 instrument span Level - Low Low SR 3.3.2.9 SR 3.3.2.10 Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Safety Injection

8. ESFAS Interlocks

a. Reactor Trip, P-4 1,2,3 2 per train, F SR 3.3.2.11 NA 2 trains

b. Pressurizer Pressure, 1,2,3 3 L SR 3.3.2.5 < 1979 psig P-11 SR 3.3.2.9 (a) The Allowable Value defines the Limiting Safety System Settings. See the Bases for the Trip Setpoints.

Wolf Creek - Unit 1 3.3-35 Amendment No. !23, 126.,!32,

PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2 and 3.

ACTIONS k IPVTr%'-

I. ;I --------------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore required channel 30 days with one required channel to OPERABLE status.

inoperable.

B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A not Specification 5.6.8.

met.

(continued)

Wolf Creek - Unit 1 3.3-36 Amendment No. 234,155,

PAM Instrumentation 3.3.3 ACTIONS (continued) _ _, _-

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions with C.1 Restore all but one 7 days two or more required channel to OPERABLE channels inoperable, status.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Table 3.3.3-1 Time of Condition C not for the channel.

met.

E. As required by Required E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in Table 3.3.3-1. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required F.1 Initiate action in Immediately Action D.1 and referenced accordance with in Table 3.3.3-1. Specification 5.6.8.

Wolf Creek - Unit 1 3.3-37 Amendment No. 123,1!57,

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

.. ir,-rr

I- JI r----------------------------------------------------------------

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 - ------------------ NOTE ----------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 18 months Wolf Creek - Unit 1 3.3-38 Amendment No. 4-2-,

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 1)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION D.1

1. Neutron Flux 2 E

2. Reactor Coolant System (RCS) Hot Leg Temperature 2 E (Wide Range)

3. RCS Cold Leg Temperature (Wide Range) 2

4. RCS Pressure (Wide Range) 2

5. Reactor Vessel Water Level 2

6. Containment Normal Sump Water Level 2

7. Containment Pressure ( Normal Range) 2

8. Steam Line Pressure 2 per steam generator

9. Containment Radiation Level (High Range) 2

10. Not Used

11. Pressurizer Water Level 2

12. Steam Generator Water Level (Wide Range) 4

13. Steam Generator Water Level (Narrow Range) 2 per steam generator

14. Core Exit Temperature - Quadrant 1 2 (a)

15. Core Exit Temperature - Quadrant 2 2(a)

16. Core Exit Temperature - Quadrant 3 2(a)

17. Core Exit Temperature - Quadrant 4 2 (a)

18. Auxiliary Feedwater Flow Rate 4

19. Refueling Water Storage Tank Level 2 (a) A channel consists of two core exit thermocouples (CETs).

Wolf Creek - Unit 1 3.3-39 Amendment No. 123,!57,

Remote Shutdown System 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown System LCO 3.3.4 The Remot 'e Shutdown System Functions in Table 3.3.4-1 and the required auxiliary shutdown panel (ASP) controls shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

-NOTE-Separate Condition entry is allowed for each Function and required ASP control.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function 30 days Functions inoperable, and required ASP controls to OPERABLE status.

OR One or more required ASP controls inoperable.

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 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Wolf Creek - Unit 1 3.3-40 Amendment No. 123, 155,

Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS _" _ _"

SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.4.2 Verify each required auxiliary shutdown panel control 18 months circuit and transfer switch is capable of performing the intended function.

SR 3.3.4.3 -------------------- NOTES ----------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. Reactor Trip Breakers and RCP breakers are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required 18 months instrumentation channel.

Wolf Creek - Unit 1 3.3-41 Amendment No. 1-23,

Remote Shutdown System 3.3.4 Table 3.3.4-1 (page 1 of 1)

Remote Shutdown System Functions FUNCTION REQUIRED CHANNELS

1. Source Range Neutron Fluxa 1

2. Reactor Trip Breaker Position 1 per trip breaker

3. Pressurizer Pressure 1

4. RCS Wide Range Pressure 1

5. RCS Hot Leg Temperature 1

6. RCS Cold Leg Temperature 1

7. SG Pressure I per SG

8. SG Level 1 per SG

9. AFW Flow Rate 1

10. RCP Breakers 1per pump

11. AFW Suction Pressure 1

12. Pressurizer Level 1

a. Not required OPERABLE in MODE 1 or in MODE 2 above the P-6 setpoint.

Wolf Creek - Unit 1 3.3-42 Amendment No. 1-2-,

LOP DG Start Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Loss of Power (LOP) Diesel Generator (DG) StartlInstrumentation LCO 3.3.5 Four channels per 4-kV NB bus of the loss of voltage Function and four channels per 4-kV NB bus of the degraded voltage Function shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4, When associated DG is required to be OPERABLE by LCO 3.8.2, "AC Sources - Shutdown."

ACTIONS

NOTI7----------------------------------------------------------------

Separate Condition entry is allowed for each Fur CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions --------------- NOTE ----------

with one channel per bus The inoperable channel may be inoperable, bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels.

A.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. One or more Functions B.1 Declare associated load Immediately with two or more channels shedder and emergency per bus inoperable, load sequencer (LSELS) inoperable.

OR Required Action and associated Completion Time of Condition A not met.

Wolf Creek - Unit 1 - 3.3-43 Amendment No. 41-2,

LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Not Used.

SR 3.3.5.2 --------------------- NOTE ----------------

Verification of time delays is not required.

Perform TADOT. 31 days SR 3.3.5.3 Perform CHANNEL CALIBRATION with nominal Trip 18 months Setpoint and Allowable Value as follows:

a. Loss of voltage Allowable Value > 82.5V, 120V bus with a time delay of 1.0 + 0.2, -0.5 sec.

Loss of voltage nominal Trip Setpoint 83V,,

1 20V bus with a time delay of 1.0 sec.

b. Degraded voltage Allowable Value > 105.9V, 120V bus with a time delay of 119 + 11.6 sec.

Degraded voltage nominal Trip Setpoint 106.9V, 120V bus with a time delay of 119 sec.

SR 3.3.5.4 Verify LOP DG Start ESF RESPONSE TIMES are 18 months on a within limits. STAGGERED TEST BASIS Wolf Creek - Unit 1 3.3-44 Amendment No. 423.,12,

Containment Purge Isolation Instrumentation 3.3.6 3.3 INSTRUMENTATION 3.3.6 Containment Purge Isolation Instrumentation LCO 3.3.6 The Containment Purge Isolation instrumentation for each Function in Table 3.3.6-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6-1.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. --------- NOTE ------- A1 Place and maintain Immediately Only applicable in containment purge supply MODE 1, 2, 3, or 4. and exhaust valves in closedposition.

One or more Functions with one or more channels or trains inoperable.

(continued)

Wolf Creek - Unit 1 3.3-45 Amendment No. 1-2-,

Containment Purge Isolation Instrumentation 3.3.6 ACTIONS (continued) .

CONDITION REQUIRED ACTION COMPLETION TIME B. --------- NOTE -------------- B.1 Place and maintain Immediately Only applicable during containment purge supply CORE ALTERATIONS or and exhaust valves in movement of irradiated closed position.

fuel assemblies within containment. OR B.2 Enter applicable Immediately One or more Functions Conditions and Required with one or more Actions of LCO 3.9.4, channels or trains "Containment inoperable. Penetrations," for containment purge supply and exhaust valves made inoperable by isolation instrumentation.

SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.6.2 --------------------- NOTE ----------------

The continuity check may be excluded.

Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS (continued)

Wolf Creek - Unit 1 3.3-46 Amendment No. 1-23,

Containment Purge Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS (continued) .... _.......

SURVEILLANCE FREQUENCY SR 3.3.6.3 Perform COT. 92 days SR 3.3.6.4 ---------------------- NOTE ------------------

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3.3.6.5 Perform CHANNEL CALIBRATION. 18 months SR 3.3.6.6 Verify Containment Purge Isolation ESF RESPONSE 18 months on a TIMES are within limits. STAGGERED TEST BASIS Wolf Creek - Unit 1 3.3-47 Amendment No. 4-23,

Containment Purge Isolation Instrumentation 3.3.6 Table 3.3.6-1 (page 1 of 1)

Containment Purge Isolation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIRED CHANNELS REQUIREMENTS TRIP SETPOINT Manual 1,2,3,4, 2 SR 3.3.6.4 NA Initiation (a),(b)

2. Automatic 1,2,3,4, 2 trains SR 3.3.6.2 NA Actuation Logic (a),(b) SR 3.3.6.6 and Actuation Relays (BOP ESFAS)

3. Containment 1,2,3,4, 1 SR 3.3.6.1 (c)

Atmosphere - (a),(b) SR 3.3.6.3 Gaseous SR 3.3.6:5 Radioactivity

4. Containment Refer to LCO 313.2, "ESFAS Instrumentation," Function 3.a, for all initiation functions and requirements.

Isolation -

Phase A (a) During CORE ALTERATIONS.

(b) During movement of irradiated fuel assemblies within containment.

(c) Trip setpoint concentration value (1.Ci/cm3) is to be established such that the actual submersion rate would not exceed mR/h in the containment building.

Wolf Creek - Unit 1 3.3-48 Amendment No. 1-2G,

CREVS Actuation Instrumentation 3.3.7 3.3 INSTRUMENTATION 3.3.7 Control Room Emergency Ventilation System (CREVS) Actuation Instrumentation LCO 3.3.7 The CREVS actuation instrumentation for eachFunction in Table 3.3.7-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.7-1.

ACTIONS

NOTE -------------- I------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with A.1 Place one CREVS train in 7 days one channel or train Control Room Ventilation inoperable. Isolation Signal (CRVIS) mode.

(continued)

Wolf Creek - Unit,1 3.3-49 Amendment No. 4-2-3,

CREVS Actuation Instrumentation 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. --------- NOTE B--------B1.1ý1 Place one CREVS train in Immediately Not applicable to Function the CRVIS mode.

3.

AND One or more Functions B.1.2 Enter applicable Immediately with two channels or two Conditions and Required trains inoperable. Actions of LCO 3.7.10, "Control Room Emergency Ventilation System (CREVS)," for one CREVS train made inoperable by inoperable CREVS actuation instrumentation.

OR B.2 Place both trains in CRVIS Immediately mode.

C. Both radiation monitoring C.1.1 Enter applicable Immediately channels inoperable. Conditions and Required Actions of LCO 3.7.10, "Control Room Emergency Ventilation System (CREVS)," for one CREVS train made inoperable by inoperable CREVS actuation instrumentation.

AND C.1.2 Place one CREVS train in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months CRVIS mode.

OR C.2 Place both trains in CRVIS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode.

(continued)

Wolf Creek - Unit 1 3.3-50 Amendment No. 1-2-3,

CREVS Actuation Instrumentation 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D .1 Be in MODE 3. -6.hours associated Completion Time for Condition A, B AND or C not met in MODE 1, 2, 3, or 4. D .2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Required Action and E:I Suspend CORE Immediately associated Completion ALTERATIONS.

Time for Condition A, B or C not met in MODE 5 or AND 6, or during movement of irradiated fuel assemblies. E..2 Suspend movement of Immediately irradiated fuel assemblies.

SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.7-1 to determine which SRs apply for each CREVS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.7.2 Perform COT. 92 days (continued)

Wolf Creek - Unit 1 3.3-51 Amendment No. 1-2-3,

CREVS Actuation Instrumentation 3.3.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.7.3 ---------------------- NOTE ------------------

The continuity check may be excluded.

Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.7.4 ---------------------- NOTE ------------------

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3.3.7.5 Perform CHANNEL CALIBRATION. 18 months Wolf Creek - Unit 1 3.3-52 Amendment No. 1-2-,

CREVS Actuation Instrumentation 3.3.7 Table 3.3.7-1 (page 1 of 1)

CREVS Actuation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS REQUIREMENTS TRIP SETPOINT

1. Manual Initiation 1, 2,3,4,5,6, 2 SR 3.3.7.4 NA and (a)

2. Automatic Actuation Logic 1, 2,3,4,5,6, 2 trains SR 3.3.7.3 NA and Actuation Relays (BOP and (a)

ESFAS)

3. Control Room Radiation- 1, 2, 3,4,5,6, 2 SR 3.3.7.1 (b)

Control Room Air Intakes and (a) SR 3.3.7.2 SR 3.3.7.5

4. Containment Isolation - Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 3.a, for all initiation functions and Phase A requirements.

(a) During movement of irradiated fuel assemblies.

(b) Trip Setpoint concentration value (pCi/cm 3) is to be established such that the actual submersion dose rate would not exceed 2 mR/hr in the control room...

Wolf Creek - Unit 1 3.3-53 Amendment No. 2-3",32,

EES Actuation Instrumentation 3.3.8 3.3 INSTRUMENTATION 3.3.8 Emergency Exhaust System (EES) Actuation Instrumentation LCO 3.3.8 The EES actuation instrumentation for each Function in Table 3.3.8-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.8-1.

ACTIONS

NOT r---------------------------------------------------------------

Separate Condition entry is allowed for each Fun CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Place one EES train in the 7 days with one channel or train Fuel Building Ventilation inoperable. Isolation Signal (FBVIS) mode.

(continued)

Wolf Creek - Unit 1 3.3-54 Amendment No. 2-,

EES Actuation Instrumentation 3.3.8 ACTIONS (continued) _ _ _

CONDITION REQUIREDACTION COMPLETION TIME B. --------- NOTE ------------- B.1.1 Place one EES train in the Immediately Not applicable to Function FBVIS mode.

3.

AND One or more Functions B.1.2 Enter applicable Immediately with two channels or two Conditions and Required trains inoperable. Actions of LCO 3.7.13, "Emergency Exhaust System (EES)," for one EES train made inoperable by inoperable EES actuation instrumentation.

OR B.2 Place both trains in the Immediately FBVIS mode.

C. Both radiation monitoring C.1.1 Enter the applicable Immediately channels inoperable. Conditions and Required Actions of LCO 3.7.13, "Emergency Exhaust System (EES)," for one EES train made inoperable by inoperable EES actuation instrumentation.

AND C.1.2 Place one EES train in the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months FBVIS mode.

OR C.2 Place both EES trains in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the FBVIS mode.

(continued)

Wolf Creek - Unit 1 3.3-55 Amendment No. 1-2-,

EES Actuation Instrumentation 3.3.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Suspend movement of Immediately associated Completion irradiated fuel assemblies Time for Condition A, B or in the fuel building.

C not met during movement of irradiated fuel assemblies in the fuel building.

SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.8-1 to determine which SRs apply for each EES Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.8.2 Perform COT. 92 days SR 3.3.8.3 ---------------------- NOTE ------------------

The continuity check may be excluded.

Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS (continued)

Wolf Creek - Unit 1 3.3-56 Amendment No. 42-2,

EES Actuation Instrumentation 3.3.8 SURVEILLANCE REQUIREMENT-S (continued)_

SURVEILLANCE FREQUENCY SR 3.3.8.4 ------------ --------- NOTE ------------------

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3:3.8.5 Perform CHANNEL CALIBRATION. 18 months Wolf Creek - Unit 1 3.3-57 Amendment No. 4-2-3,

EES Actuation Instrumentation 3.3.8 Table 3.3.8-1 (page 1 of 1)

EES Actuation Instrumentation APPLICABLE MODES OR SPECIFIED REQUIRED SURVEILLANCE TRIP FUNCTION CONDITIONS CHANNELS REQUIREMENTS SETPOINT

1. Manual Initiation (a) 2 SR 3.3.8.4 NA

2. Automatic Actuation Logic and (a) 2 trains SR 3.3.8.3 NA Actuation Relays (BOP ESFAS)

3. Fuel Building Exhaust Radiation -

Gaseous (a) 2 SR 3.3.8.1 (b)

SR 3.3.8.2 SR 3.3.8.5 (a) During movement of irradiated fuel assemblies in the fuel building.

(b) Trip Setpoint concentration value (_LCi/cm 3) is to be established such that the actual submersion dose rate would not exceed 4 mR/hr in the fuel building.

Wolf Creek - Unit 1 3.3-58 Amendment No. 4-24,

Attachment IV to ET 08-0041 Page 1 of 5 Proposed TS Bases Changes (for information only)

Attachment IV to ET 08-0041 Page 2 of 5 ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE SR 3.3.2.4 (continued)

REQUIREMENTS large enough to demonstrate signal path continuity. This test is performed every 92 days~on a STAGGERED TEST BASIS. The time allowed for the testing (4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ) is justified in Reference 7. The Frequency of every 92 days on a STAGGERED TEST BASIS is justified in Reference 13.

SR 3.3.2.5 SR 3.3.2.5 is the performance of a COT.

A COT is performed on each required channel to ensure the channel will perform the intended Function. Setpoints must be found within the Allowable Values specified in Table 3.3.2-1.

The setpoint shall be left set consistent with the assumptions of the current unit specific setpoint methodology.

The Frequency of 184 days is justified in Reference 13.

SR 3.3.2.6 SR 3.3.2.6 is the performance of a SLAVE RELAY TEST. The SLAVE RELAY TEST is the energizing of the slave relays. Contact operation is verified in one of two ways. Actuation equipment that may be operated in the design mitigation MODE is either allowed to function, or is placed in a condition where the relay contact operation can be verified without operation of the equipment. Actuation equipment that may not be operated in the design mitigation MODE is prevented from operation by the slave relay blocking circuit. For this latter case, contact operation is veMifiec by and unction cc * (u teThin/requen test is performed eve Tripu and s adte luate slave based/on r

ind 0 ig ei* E!, Oieig r me ltrelifi'lit a* )

indd'esting :? qiu~ire yR 3 R...

For Function 4.c (Steam Line Isolation -Automatic Actuation Logic (MSFIS)) and Function 5.b (Turbine Trip and Feedwater Isolation - I Automatic Actuation Logic (MSFIS)), SR 3.3.2.6 is performed on the associated slave relays in the SSPS cabinets and includes verification that the slave relays are energized at the MSFIS cabinets.

-W~sFr~eer~xecy m~ ýDseA cmV miav. IrIAIiAVrx 0!_C Ster4h pre-sen~eA Vt'Y WCAP-MS3WW-P-A,"60L6M As56sv~evit e4ý -PC*ev k Fwrumf~ I.i At-11R ser ýe6 P'Jk&yS, (9'e -1 j.i%," e. rctAA*

mr mtk SPe_+' AM& R~wiy 6" it CPo*"ey-ý1'ufik D c *e;ý 'r_______

Wolf Creek - Unit 1 B 3.3.2-47 Revision 37

Attachment IV to ET 08-0041 :,:,

Page 3 of 5 ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE SR 3.3.2.10 (continued).

REQUIREMENTS (continued) response time, is included in the'testing of each channel. The final'.

actuation device in one train is tested with each channel. Therefore, staggered testing results in response time verification-of these devices every 18 months. The 18 month Frequency is consistent with the typical refueling cycle and is based on unit operating experience, which shows that random failures of instrumentation components causing serious response time degradation, but not channel failure, are ,infrequent, occurrences.

This SR is modified by a Note that clarifies that the turbine driven AFW pump is tested within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reaching 900 psig in the SGs.

SR 3.3.2.11 SR 3.3.2.11 is the performance of a TADOT as described inSR 3.3.2.8 except that it is performed for the P-4 Reactor Trip Interlock, and the Frequency is every 18 months. This Frequency is based on operating experience.

The SR is modified by a Note that excludes verification of setpoints during the TADOT. The Function tested has no associated setpoint. This TADOT does not include the circuitry associated with steam dump operation since it is control grade circuitry.

SR 3.3.2.12 SR 3.3.2.12 is the performance of a monthly COT on ESFAS Function 6.h, "Auxiliary Feedwater Pump Suction Transfer on Suction Pressure - Low."

A COT is performed to ensure the channel will perform the intended' Function. Setpoints must be found within the Allowable Values specified in Table 3.3.2-1.

The setpoint shall be left set consistent with the assumptions of the current unit specific setpoint methodology.

SR 3.3.2 5 .3.2.13 is th erformance a SLAVE RE Y TEST as ibe ZR 2.,eý R 3.3.2.6, e ppt thatec~

that SI;:

SR 3. . .213 has a N e,specifyin at itt aot6e apl*es Wolf Creek - Unit 1 B 3.3'.2-51 Revision 20 1

Attachment IV to ET 08-0041 Page 4 of 5 ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE SR 3.3.2.13 contin d).

REQUIREMENTS only slave re ys K602, 22, K62 630, K74 ,and K741. These sI e relays re tested a Freq ncy of 18im nths anid prior ntering DE 4 for unctions ,3.a.(2), a 7.a whenev . he unit has b in MOD or 6 for 24 hous if t performed 4fthin the pre us 92 da (Referen 9) 1 onth Fequey for these slave rr~ys isbas on the n d to perfor' his Surveilla/e under the ondition at apply ring a unit age to avoid e potential for n unplan d transien the Surveil nce were pe rmed with the actorat R *.32.1 SR 3. .14 is the rformance of SLAVE RELA EST as describ in SR 3,3.2.6, exc that SR 3.3. .14 has a Note ecifying that it a lies o y s a rý ay K620. Th SLAVE RELAY EST of relay K6 does ot include e circuitry a ociated with the ain feedwater mp trip solenoid since that cir itry serves no r uired safety fu ion. This slave lay is tested ith a Frequency 18 months an prior to entering M E 2 for Funct n 5.a whenever e unit has bee in MODE 5 or 6 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , if n performed withi e previous 9 days (Reference 9 The 18 mont requency for thi slave relay is sed on the need perform t Surveillance un r the condition that apply during unit outage avoid the potent or an unplan d transient if the urveillance were erformed with the eactor at powe REFERENCES, 1. USAR, Chapter 6.

2. USAR, Chapter 7.

3. USAR, Chapter 15.

4. IEEE-279-1971.

5. 10 CFR 50.49.

6. WCNOC Nuclear Safety Analysis Setpoint Methodology for.the Reactor Protection System, TR-89-0001.

7. WCAP-10271-P-A Supplement 2, Revision 1, "Evaluation of Surveillance Frequencies and Out of Service Times for the Engineered Safety Features Actuation System," June 1990.

8. WCAP-13632-P-A, Revision 2, "Elimination of Pressure Sensor Response Time Testing Requirements," January- 1996. -

Wolf Creek - Unit 1 B 3.3.2-52 Revision 20.

Attachment IV to El 0041 Page 5 of 5 ESFAS Instrumentation B 3.3.2 LVJ C;AP- il8-e, - P-A 2 Retir b , e ~l/ ~~elZc BASES REFERENCES 9. ~94 (continued)

10. "Wolf Creek Setpoint Methodology Report," SNP (KG)-492, August 29, 1984.

11. Amendment No. 43 to Facility Operating License No. NPF-42, March 29, 1991.

12. WCAP-14333-P-A, Revision 1, "Probabilistic Risk Analysis of the RPS and ESFAS Test Times and Completion Times," October 1998.

13. WCAP-1 5376-P-A, Revision 1, "Risk-Informed Assessment of the RTS and ESFAS Surveillance Test Intervals and Reactor Trip Breaker Test and Completion Times," March 2003.

14. 10 CFR 50.55a(b)(3)(iii), Code Case OMN 1

15. Performance Improvement Request __.2005-2067.

Wolf Creek - Unit 1 B 3.3.2-53 Revision 25

Attachment V to ET 08-0041 Page 1 of 1 LIST OF REGULATORY COMMITMENTS The following table identifies those actions committed to by WCNOC in this document. Any other statements in this submittal are provided for information purposes and are not considered to be regulatory commitments.

REGULATORY COMMITMENTS DUE DATE I EVENT Once approved, the amendment will be implemented within 90 Within 90 days of NRC days. approval

ET 08-0041, Revision to Technical Specification 3.3.2, Engineered Safety Feature Actuation System (ESFAS) Instrumentation.

Contents

Text

Subject:

SUMMARY

3.0 TECHNICAL EVALUATION

4.0 REGULATORY EVALUATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 REFERENCES

SUMMARY

3.0 TECHNICAL EVALUATION

4.0 REGULATORY EVALUATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 REFERENCES

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ET 08-0041, Revision to Technical Specification 3.3.2, Engineered Safety Feature Actuation System (ESFAS) Instrumentation.

Text

Subject:

SUMMARY

3.0 TECHNICAL EVALUATION

4.0 REGULATORY EVALUATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 REFERENCES

SUMMARY

3.0 TECHNICAL EVALUATION

4.0 REGULATORY EVALUATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 REFERENCES

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