ML11334A046

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Request for Amendment to Various Technical Specifications to Implement Administrative Changes
ML11334A046
Person / Time
Site: Palo Verde  Arizona Public Service icon.png
Issue date: 11/22/2011
From: Mims D
Arizona Public Service Co
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
102-06445-DCM/DFS
Download: ML11334A046 (32)
v • d • e


Text

10 CFR 50.90 iAL- A subsidiary of Pinnacle West CapitalCorporation Dwight C. Mims Mail Station 7605 Palo Verde Nuclear Senior Vice President Tel. 623-393-5403 P.O. Box 52034 Generating Station Nuclear Regulatory and Oversight Fax 623-393-6077 Phoenix, Arizona 85072-2034 102-06445-DCM/DFS November 22, 2011 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Dear Sirs:

Subject:

Palo Verde Nuclear Generating Station (PVNGS)

Units 1, 2, and 3 Docket Nos. STN 50-528, 50-529, and 50-530 Request for Amendment to Various Technical Specifications to Implement Administrative Changes Pursuant to 10 CFR 50.90, Arizona Public Service Company (APS) hereby requests to amend the Technical Specifications (TS) that are incorporated as Appendix A to the Renewed Operating License Nos. NPF-41, NPF-51, and NPF-74 for Palo Verde Nuclear Generating Station (PVNGS) Units 1, 2, and 3, respectively. The proposed license amendment request (LAR) will make administrative and editorial changes to clarify and align the existing TSs.

The changes include corrective actions from the Unit 2 event described in Licensee Event Report (LER) 50-529/2011-001. The proposed changes are detailed in the enclosure to this letter.

Approval of the proposed amendment is requested by November 30, 2012. Once approved, the amendment shall be implemented within 90 days. No commitments are being made to the NRC by this letter.

In accordance with the PVNGS Quality Assurance Program, the Plant Review Board and the Offsite Safety Review Committee have reviewed and concurred with this proposed amendment. By copy of this letter, this submittal is being forwarded to the Arizona Radiation Regulatory Agency (ARRA) pursuant to 10 CFR 50.91 (b)(1).

Should you need further information regarding this LAR, please contact Russell A.

Stroud, Licensing Section Leader, at (623) 393-5111.

A member of the STARS (Strategic Teaming and Resource Sharing)

Alliance ODJ Callaway 0 Comanche Peak 0 Diablo Canyon 0 Palo Verde 0 San Onofre 0 South Texas 0 Wolf Creek

ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Request for Amendment to Various Technical Specifications to Implement Administrative Changes Page 2 I declare under penalty of perjury that the foregoing is true and correct.

Executed on ,)OOF,,OF*-,A* .,Rd.tOO (Date)

Sincerely,

,,,* *A 1 , -

DCM/RAS/DFS/gat

Enclosure:

Evaluation of the Proposed Change cc: E. E. Collins, Jr. NRC Region IV Regional Administrator B. K. Singal NRC NRR Project Manager for PVNGS L. K. Gibson NRC NRR Project Manager J. R. Hall NRC NRR Senior Project Manager M. A. Brown NRC Senior Resident Inspector for PVNGS A. V. Godwin Arizona Radiation Regulatory Agency (ARRA)

T. Morales Arizona Radiation Regulatory Agency (ARRA)

ENCLOSURE Evaluation of the Proposed Change

Subject:

Request for Amendment to Various Technical Specifications to Implement Administrative Changes 1.0

SUMMARY

DESCRIPTION 2.0 DETAILED DESCRIPTION

3.0 TECHNICAL EVALUATION

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements/Criteria 4.2 No Significant Hazards Consideration Determination 4.3 Conclusions

5.0 ENVIRONMENTAL CONSIDERATION

6.0 REFERENCES

ATTACHMENTS:

1. Technical Specification Page Markups
2. Retyped Technical Specification Pages

Enclosure Evaluation of the Proposed Change 1.0

SUMMARY

DESCRIPTION Pursuant to 10 CFR 50.90, Arizona Public Service Company (APS) hereby requests to amend the Technical Specifications (TS) that are incorporated as Appendix A to the Renewed Operating License Nos. NPF-41, NPF-51, and NPF-74 for Palo Verde Nuclear Generating Station (PVNGS) Units 1, 2, and 3, respectively. The proposed license amendment request (LAR) will make administrative and editorial changes to clarify and align the existing TSs.

The proposed changes are administrative or editorial, and will not result in any change to operating requirements. The proposed changes remove duplicate TS requirements and unit specific references that are no longer needed. In addition, the proposed administrative changes correct typographical errors and provide clarification to ensure understanding of the required actions of some TSs. The changes include corrective actions from the Unit 2 event described in Licensee Event Report (LER) 50-529/2011-001. These administrative changes are proposed for the following Technical Specifications (TS):

" TS 3.3.1 "Reactor Protective System (RPS) Instrumentation - Operating"

  • TS 3.3.2 "Reactor Protective System (RPS) Instrumentation - Shutdown"

" TS 3.3.5 "Engineered Safety Features Actuation System (ESFAS) Instrumentation"

" TS 3.5.5 "Refueling Water Tank (RWT)"

  • TS 3.3.9 "Control Room Essential Filtration Actuation Signal (CREFAS)"

" TS 3.7.11 "Control Room Essential Filtration System (CREFS)"

" TS 5.4 "Procedures"

" TS 5.5.16 "Containment Leakage Rate Testing Program" 2.0 DETAILED DESCRIPTION The following changes are proposed:

  • TS 3.3.1 "Reactor Protective System (RPS) Instrumentation - Operating" In Table 3.3.1-1 "Reactor Protective System Instrumentation," for Functions 6 and 7 delete reference to "3990 MWt RTP" from the "Allowable Value" column.
  • TS 3.3.2 "Reactor Protective System (RPS) Instrumentation - Shutdown" In Table 3.3.2-1 "Reactor Protective System Instrumentation - Shutdown," for Functions 2 and 3 delete reference to "3990 MWt RTP" from the "Allowable Value" column.

2

Enclosure Evaluation of the Proposed Change TS 3.3.5 "Engineered Safety Features Actuation System (ESFAS) Instrumentation" In Table 3.3.5-1 "Engineered Safety Features Actuation System Instrumentation," for Functions 4a and 4b delete reference to "3990 MWt RTP" from the "Allowable Value" column.

The references to "3990 MWt RTP" in the tables above are no longer needed and can be removed as a result of the completion of the Power Uprate in all three PVNGS units. Deletion of these references removes unnecessary detail.

TS 3.3.5 "Engineered Safety Features Actuation System (ESFAS) Instrumentation" Delete the "Pre-RW-T TS Setpoint Change" (page 3.3.5-4) version of Table 3.3.5-1 "Engineered Safety Features Actuation System Instrumentation," and remove the words "After RWT TS Setpoint Change," from remaining version of Table 3.3.5-1 (page 3.3.5-5). This will include renumbering the TS pages.

As provided in approved License Amendment 182 (Reference 6.1), the changes to the RWT level setpoints were to be implemented as the supporting modifications in each PVNGS units were completed. These modifications have been completed and the "After RWT TS Setpoint Change" Function 5a values are now fully implemented in Units 1, 2, and 3. As a result, the "Pre-RWT TS Setpoint Change" version of the table is no longer needed and can be removed.

  • TS 3.3.9 "Control Room Essential Filtration Actuation Signal (CREFAS)"

Revise the Required Actions A.1 and C.1 from "Place one CREFS train in operation," to "Place one CREFS train in essential filtration mode."

This revision is to clarify the Required Actions and to ensure complete understanding of the configuration necessary to meet those Actions. The change is a corrective action from the Unit 2 event described in LER 50-529/2011-001.

Delete the "Pre-RWT TS Setpoint Change" (page 3.5.5-3) version of Figure 3.5.5-1 Minimum Required RWT Volume and remove the words "After RWT TS Setpoint Change," from remaining version of Figure 3.5.5-1 (page 3.3.5-4). This will include renumbering the remaining TS page.

As provided in approved License Amendment 182, the changes to the RWT level setpoints were to be implemented as the supporting modifications in each PVNGS units were completed. These modifications have been completed and the "After RWT TS Setpoint Change" minimum required RWT values are now fully implemented in Units 1, 2, and 3. As a result, the "Pre-RWT TS Setpoint Change" version of the figure is no longer needed and can be removed.

3

Enclosure Evaluation of the Proposed Change

" TS 3.7.11 "Control Room Essential Filtration System (CREFS)"

Revise the Required Actions D.1 and E.1 from "Place OPERABLE CREFS train in operation," to "Place OPERABLE CREFS train in essential filtration mode."

This revision is to clarify the Required Actions and to ensure complete understanding of the configuration necessary to meet those Actions. The change is a corrective action from the Unit 2 event described in LER 50-529/2011-001.

" TS 5.4 "Procedures" In the second paragraph in TS 5.4.1.f, add an open quotation mark preceding the words Software Program Manual for CommonQ Systems, and move the comma trailing these words inside the closed quotation mark.

This is correcting typographical errors.

  • TS 5.5.16 "Containment Leakage Rate Testing Program" Revise TS 5.5.16.b to remove historical data on the calculated containment internal pressures (Pa) for each of the PVNGS units and confirm that the current (Pa) for all three units is 58.0 psig.

This change is editorial and removes historical information that is confusing and unnecessary.

3.0 TECHNICAL EVALUATION

The proposed changes to the TSs are administrative and editorial and do not affect how plant equipment is operated or maintained. No changes to the physical plant or analytical methods are proposed and there are no impacts to the PVNGS Updated Final Safety Analysis Report (UFSAR) accident analysis.

List of Proposed Administrative Changes Proposed Change Justification Technical Specification Sections Remove reference to 3990 Removes historical information no longer required 3.3.1, 3.3.2, and megawatts thermal (MWt). (reference Facility Operating License Amendment 157). 3.3.5 Delete the "Pre-RWT TS The RWT setpoint changes in License Amendment 182 3.3.5 Setpoint Change" version have been implemented in all three PVNGS units. As a of Table result, the Pre- RWT TS Setpoint Change information is 3.3.5-1 and remove the no longer needed and can be removed.

words "After RWT TS Setpoint Change," from remaining version of Table 3.3.5-1.

4

Enclosure Evaluation of the Proposed Change Proposed Change Justification Technical Specification Sections Revise the TS 3.3.9, This revision is to clarify the Required Actions and to 3.3.9 Required Actions A. 1 and ensure complete understanding of the configuration C.1 to "Place one CREFS necessary to meet those actions. This clarification uses train in essential filtration more precise language to ensure consistency with the mode." PVNGS design and licensing basis. TS 3.3.9 Bases reflect that the essential filtration mode is the equivalent to the emergency mode as provided in NUREG-1432, Revision 3 (Reference 6.2) and ensures that the alignment of the CREFS will mitigate a design basis accident.

Delete the "Pre-RWT TS The RWT setpoint changes in License Amendment 182 3.5.5 Setpoint Change" version have been implemented in all three PVNGS units. As a of Figure 3.5.5-1 and result, the Pre-RWT TS Setpoint Change information is no remove the words "After longer needed and can be removed.

RVVT TS Setpoint Change," from remaining version of Figure 3.5.5 -1.

Revise the TS 3.7.11 This revision is to clarify the Required Actions and to 3.7.11 Required Actions D.1 and ensure complete understanding of the configuration E.1 to "Place OPERABLE necessary to meet those actions. This clarification uses CREFS train in essential more precise language to ensure consistency with the filtration mode." PVNGS design and licensing basis. TS 3.7.11 Bases reflect that the essential filtration mode is the equivalent to the emergency mode as provided in NUREG-1432, Revision 3 (Reference 6.2) and ensures that the alignment of the CREFS will mitigate a design basis accident.

TS 5.4.1.f, add an open Correction of typographical errors. 5.4.1.f quotation mark preceding the words Software ProgramManual for Common Q Systems, and move the comma trailing these words inside the closed quotation mark.

Revise TS 5.5.16.b to Removes historical information no longer required 5.5.16 reflect the current (Pa) for (reference Facility Operating License Amendment 157).

each unit being 58.0 psig.

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements/Criteria The proposed changes to the TSs are administrative and editorial, and do not affect any regulatory requirements or criteria. These changes do not affect how plant equipment is operated or maintained and there are no changes to the physical plant or analytical methods. As a result, there are no impacts to the PVNGS UFSAR accident analysis.

5

Enclosure Evaluation of the Proposed Change 4.2 No Significant Hazards Consideration Determination The proposed changes are administrative and editorial, and do not modify the existing licensing basis or operating requirements. The proposed changes remove technical specification (TS) requirements and unit specific references that are no longer required.

In addition, the proposed administrative changes address some typographical errors and provide clarification to ensure understanding of the required actions of some TSs.

The proposed amendment includes the following changes that are considered to be administrative and editorial changes:

" TS 3.3.1 "Reactor Protective System (RPS) Instrumentation - Operating," Table 3.3.1-1, Functions 6 and 7 delete reference to "3990 MWt RTP."

  • TS 3.3.2 "Reactor Protective System (RPS) Instrumentation - Shutdown," Table 3.3.2-1, Functions 2 and 3 delete reference to "3990 MWt RTP."

" TS 3.3.5 "Engineered Safety Features Actuation System (ESFAS) Instrumentation,"

Table 3.3.5-1, Functions 4a and 4b delete reference to "3990 MWt RTP."

" TS 3.3.5 "Engineered Safety Features Actuation System (ESFAS) Instrumentation,"

delete the "Pre-RVVT TS Setpoint Change" version of Table 3.3.5-1 and remove the words "After RWT TS Setpoint Change," from remaining version of Table 3.3.5-1.

" TS 3.3.9 "Control Room Essential Filtration Actuation Signal (CREFAS)," revise Required Actions A.1 and C.1 to "Place one CREFS train in essential filtration mode."

" TS 3.5.5 "Refueling Water Tank (RWT)," delete the "Pre-RVVT TS Setpoint Change" version of Figure 3.5.5-1 and remove the words "After RWT TS Setpoint Change,"

from remaining version of Figure 3.5.5-1.

" TS 3.7.11 "Control Room Essential Filtration System (CREFS)," revise the Required Actions D.1 and E.1 to "Place OPERABLE CREFS train in essential filtration mode."

  • TS 5.4 "Procedures," typographical correction to add an open quotation mark and move the comma.

" TS 5.5.16 "Containment Leakage Rate Testing Program," remove historical data on the calculated containment internal pressures (Pa) for each of the PVNGS Units and confirm that the current (Pa) for all three units is 58.0 psig.

Arizona Public Service (APS) 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:

6

Enclosure Evaluation of the Proposed Change

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

Response: No.

The proposed amendment involves administrative and editorial changes. The proposed amendment does not impact any accident initiators, analyzed events, or assumed mitigation of accident or transient events. The proposed changes do not involve the addition or removal of any equipment or any design changes to the facility. The proposed changes do not affect any plant operations, design function, or analysis that verifies the capability of structures, systems, and components (SSCs) to perform a design function. The proposed changes do not change any of the accidents previously evaluated in the UFSAR. The proposed changes do not affect SSCs, operating procedures, and administrative controls that have the function of preventing or mitigating any of these accidents.

Therefore, the proposed changes do not represent 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 amendment involves administrative and editorial changes. No actual plant equipment or accident analyses will be affected by the proposed changes. The proposed changes will not change the design function or operation of any SSCs.

The proposed changes will not result in any new failure mechanisms, malfunctions, or accident initiators not considered in the design and licensing basis. The proposed amendment does not impact any accident initiators, analyzed events, or assumed mitigation of accident or transient events.

Therefore, the proposed changes do not create the possibility of an accident of a new or different kind than previously evaluated.

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

Response: No The proposed amendment involves administrative and editorial changes. The proposed changes do not involve any physical changes to the plant or alter the manner in which plant systems are operated, maintained, modified, tested, or inspected. The proposed changes do not alter the manner in which safety limits, limiting safety system settings or limiting conditions for operation are determined.

The safety analysis acceptance criteria are not affected by the changes. The proposed changes will not result in plant operation in a configuration outside the 7

Enclosure Evaluation of the Proposed Change design basis. The proposed changes do not adversely affect systems that respond to safely shut down the plant and to maintain the plant in a safe shutdown condition.

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

Based on the above, APS concludes that the proposed amendment does not involve a significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of "no significant hazards consideration" is justified.

4.3 Conclusion 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.

5.0 ENVIRONMENTAL CONSIDERATION

A review has determined that the proposed administrative and editorial changes will not revise a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or change an inspection or surveillance requirement. The proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or a 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 amendment 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 amendment.

6.0 REFERENCES

6.1 Amendment No. 182 to Facility Operating License No. NPF-41, Amendment No.

182 to Facility Operating License No. NPF-51, and Amendment No. 182 to Facility Operating License No. NPF-74 for Palo Verde, Units 1, 2, and 3, respectively, dated November 24, 2010 (ADAMS Accession No. ML102710312) 6.2 NUREG-1432, Standard Technical Specifications Combustion Engineering Plants, Volume 1, Revision 3.0, June 2004 8

ATTACHMENT I Technical Specification Page Markups Pages:

3.3.1-7 3.3.2-5 3.3.5-4 (Deleted) 3.3.5-5 3.3.9-1 3.3.9-2 3.5.5-3 (Deleted) 3.5.5-4 3.7.11-2 5.4-1 5.5-16

RPS Instrumentation - Operating 3.3.1 Table 3.3.1-1 (page 1 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

1. Variable Over Power 1.2 SR 3.3.1.1 Ceiling _<111.0% RTP SR 3.3.1.4 Band _<9.9% RTP SR 3.3.1.6 Incr. Rate < 11.0%/min RTP SR 3.3.1.7 Decr. Rate > 5%/sec RTP SR 3.3.1.8 SR 3.3.1.9 SR 3.3.1.13
2. Logarithmic Power Level - High(a) 2 SR 3.3.1.1 < 0.011% NRTP SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13
3. Pressurizer Pressure - High 1,2 SR 3.3.1.1 < 2388 psia SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13
4. Pressurizer Pressure - Low 1,2 SR 3.3.1.1 _ 1821 psia SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13
5. Containment Pressure - High 1.2 SR 3.3.1.1 _ 3.2 psig SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13
6. Steam Generator #1 Pressure - Low 1,2 SR 3.3.1.1 900Q W1.t1FPTP: _>955 psia(aa)

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

7. Steam Generator #2 Pressure - Low 1.2 SR 3.3.1.1 449 44~ RPiP Ž 955 pSia~aa, SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 (conti nued)

(a) Trip may be bypassed when logarithmic power is > 1E-4% NRTP. Bypass shall be automatically removed when logarithmic power is

(aa) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint. or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point: otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3 3.3.1-7 AMENDMENT NO. 4.--ý.

RPS Instrumentation - Shutdown 3.3.2 Table 3.3.2-1 Reactor Protective System Instrumentation - Shutdown APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALVE

1. Logarithmic Power Level-High(d) 3 (a), 4 (a). 5 (a) SR 3.3.2.1  ! 0.011% NRTP(c)

SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.4 SR 3.3.2.5

2. Steam Generator #1 Pressure-Low(b) 3 (a) SR 3.3.2.1 3 4WtRTKP Ž 955 psia(4 X90 SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.5
3. Steam Generator #2 Pressure-Low(b) 3 (a) SR 3.3.2.1 39z P.T. 955 psia4i SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.5 (a) With any Reactor Trip Circuit Breakers (RTCBs) closed and any control element assembly capable of being withdrawn.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained

  • 200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The setpoint must be reduced to

  • 1E-4% NRTP when less than 4 RCPs are running.

(d) Trip may be bypassed when logarithmic power is > 1E-4% NRTP. Bypass shall be automatically removed when logarithmic power is

  • IE-4% NRTP.

(e) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point: otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint, 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3 3.3.2-5 AMENDMENT NO. 41-F-4, 4;-ý

After RWT TS se*rtp-# Chang ESFAS Instrumentation 3.3.5 Table 3.3.5-1 (page 1 of 1)

Engineered Safety Features Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED FUNCTION CONDITIONS ALLOWABLE VALUE

1. Safety Injection Actuation Signal
a. Containment Pressure - High 1,2,3
  • 3.2 psig
b. Pressurizer Pressure - Low(a) > 1821 psia
2. Containment Spray Actuation Signal
a. Containment Pressure - High High 1,2,3
  • 8.9 psig
3. Containment Isolation Actuation Signal
a. Containment Pressure - High 1.2,3
  • 3.2 psig
b. Pressurizer Pressure - Low(a) > 1821 psia
4. Main Steam Isolation Signal(c)
a. Steam Generator #1 Pressure-Low(b) 1,2.3 2390 M1;t RTP; 955 psia"I
b. Steam Generator #2 Pressure-Low(b) 2990 MIt R-TP:- 955 psia")
c. Steam Generator #1 Level-High
  • 91.5%
d. Steam Generator #2 Level-High < 91.5%
e. Containment Pressure-High < 3.2 psig
5. Recirculation Actuation Signal
a. Refueling Water Storage Tank Level-Low 1,2,3 > 9.15 and 9 . 6 5 %(d)
6. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-1)
a. Steam Generator #1 Level-Low 1,2,3 Ž 25.3%
b. SG Pressure Difference-High
  • 192 psid
7. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2)
a. Steam Generator #2 Level-Low 1,2.3 2 25.3%
b. SG Pressure Difference-High
  • 192 psid (a) The setpoint may be decreased to a minimum value of 100 psia. as pressurizer pressure is reduced, provided the margin between pressurizer pressure and the setpoint is maintained t 400 psia or Ž 140 psia greater than the saturation pressure of the RCS cold leg when the RCS cold leg temperature is

Ž 485°F. Trips may be bypassed when pressurizer pressure is < 400 psia. Bypass shall be automatically removed when pressurizer pressure is Ž 500 psia. The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained

  • 200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The Main Steam Isolation Signal (MSIS) Function (Steam Generator Pressure - Low, Steam Generator Level-High and Containment Pressure - High signals) is not required to be OPERABLE when all associated valves isolated by the MSIS Function are closed.

(d) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point: otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance criteria band. and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3 3. 3. 5- AMENDMENT NO. 4-7, 1

Pro RWT TS 4Sotpont Change ESFAS Instrumentation 3.3.5 Tqble 3.3.5 1 (page 1 at 1)

Engi neered Safety Features Actuation System Inetrumentati on APPI C-AB^,LE MODES OP OTHER SPECIFIrED g4NSTVNCO,*m!T!,NS ALLOWABLE VALUE

1. Safety=,,_* Injection Aetuatien... Signel a' Coritainment Pre,-ur'e Hi *,- - 2 b.Proes'..i eer Pressure ....e,,---*"P* pi 2 CrtinmntSp;ay ActuationA Signal
e. Cot.in.en. Press'ure H1gh High 8.9si
e. Conainment... Pressure... High . 4-r2--3, b pp1821 ,ps;&

.1. Mete' Steam Lolahanlr Signa!l-W'

a. S*team,,* C.enerat~er #2 Freessure Le;'...,43 3990 MN! RTP: Ž 95EEpci a*

a.Steam Corereter #/2 Pr'eevo- Lý 4 3Fi Lu neFr 1 L Hq Wi 5.F f _,jpl nor, Aetu~~jr non sian a F 6enlin 1 qWter Sturoaq 1-".

(1btt*ener e r ! L FL~o.

Tani. L-evel. ALeei 4----6.9 endp c 7 b SG' Pre tsure Difference High_ !2pd A amI-cAn.rator #2 Level LI.

b. e S(.!tpi qrlt.S-' nqi y F*,,,. . tqi ý 9t. bSi *C()Q t Pr'vý:1 t11e ar-9in betwoc poceri p cr ace the eetpcn nt is mainaine 130 > 1 6 6 a"i heýnvners'od T6,prý of3 n-atCl nre9s4r a th'6r kll-r<

Aflfle"4!"ý l(>

h ir, 1, 1,; eyei nt .... proe s ni z,,,on ,-pr ess J... U re i1,n ...hera -c.ed e ,:e h :,..,.,,.**,,,tF m er *r F . e

........ ... ....... ý! prqtjg sr Tler ;rc nA 4ý iý4 4 G Ca!; hle p 4.

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"_-cid the oinT et~poirlmay inedperassed rlt~a! ned as£ 0O'amepi P 13 eSre The is red-ue eha!!

eefpoint, provided

!£ed. the m*argin bethae be autamatica~ly1 !nrr a6 bee.I toian'ahept-pr]une n.

nrma.!

etyln aeteam peer sm c) Td Mare Steam Ieelat~i c S.gr, q (W.-*I Funectioan (Steam Generaalr Press-re Le,;-, Ste-, rCr ar I eel

';Gealed by the ,SIS uneti L r e .

-'tanpe ab!ed.

ic01 cetr

&etj~~~et'iti i p 1)i:

'qt'shet AeWel 7 Vaue. h 4 'hNnel AS-4 u P-'P" f

2. The inst n-ment channel setp,,i rtt hol.halbe reset t~o a va*lue*- thk at it e.'thic, thec as left te:leranc" 'of the OFSA, Trip Setpei nt, reF .- thin t hc,,e a: left to]eranee of a etpint that ie mare cerserv~ati, e than th. U44A^ Trp Set Piýr-nt: ethee l-,tehannel shall be dcred t inepereb!o The ,EAR Trip Satpoint and the methodology used t .determie 1)The LFSAR Trip Setpoint, 2) the pAedeterminon a: fe-nd acceptance criteria band and 3) the as left setpaint tolerance band are specifed in the UFSAR.

PALO VERDE UNITS 1,2,3 3.3.5-4 AMENDMENT NO. 17-9, 4-92 1

CREFAS 3.3.9 3.3 INSTRUMENTATION 3.3.9 Control Room Essential Filtration Actuation Signal (CREFAS)

LCO 3.3.9 One CREFAS channel shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CREFAS Manual Trip, A.1 Place one CREFS train 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Actuation Logic, or in essential filtration radiation monitor modeperae9.

inoperable in MODE 1, 2, 3, or 4.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)

PALO VERDE UNITS 1.2,3 3.3.9-1 AMENDMENT NO. 4-1;

CREFAS 3.3.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. CREFAS Manual Trip, C.1 Place one CREFS train Immediately Actuation Logic, or in essential filtration radiation monitor modeper-ýG4.

inoperable in MODE 5 or 6, or during OR movement of irradiated fuel assemblies. C.2.1 Suspend movement of Immediately irradiated fuel assemblies.

AND C.2.2 Suspend positive Immediately reactivity additions.

AND C.2.3 Suspend CORE Immediately ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.9.1 Perform a CHANNEL CHECK on the required 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> control room radiation monitor channel.

(continued)

PALO VERDE UNITS 1,2,3 3.3.9-2 AMENDMENT NO. ý

RWT PD-,e RWT TS sctpint C'hannge 3.5.5 624,000 GAL / 83%

601,000 GAL /79.9% (210°F)

G N

b M

U DELETE THIS FIGURE AND R PAGE AVERAGE RCS TEMPERATURE FIGURE 3.5.5 1 Min#imumH Deqyured RWT Volulme P,44LO VERDE UNITS 1,2,3 AHPNPM9NT-446-!;;

[ 182

RWT A-P4- DLIT TC 0-4---ý-+-

3.5.5 634,000 GAL / 84.3% (565-F) 611,000 GAL /8 1.2% (210°F) 650,000 85%'

625,000 8o%,- 600,000 575,000 0 75%+ .-J z

550,000 I.-

zu.I 70%4. 525,000 I-500,000 w

.-J w 65%

I-. 475,000 II l U -

0 100 200 )00 400 500 600 AVERAGE RCS TEMPERATURE (oF)

FIGURE 3.5.5-1 Minimum Required RWT Volume PALO VERDE UNITS 1,2,3 3. 5. 5 AMENDMENT NO.

177 182 1

CREFS 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A or AND B not met in MODE 1, 2, C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> 3, or 4.

D. Required Action and D.1 Place OPERABLE Immediately associated Completion CREFS train in Time of Condition A not essential filtration met in MODE 5 or 6. modeper-at~en.

E. Required Action and E.1 Place OPERABLE Immediately associated Completion CREFS Train in Time of Condition A not essential filtration met during movement of modngep e..- .

irradiated fuel assemblies. OR Immediately E.2 Suspend movement of irradiated fuel assemblies.

F. Two CREFS trains F.1 Suspend CORE Immediately inoperable in MODE 5 or ALTERATIONS.

6, or during movement of irradiated fuel AND assemblies.

OR One or more CREFS trains F.2 Suspend movement of Immediately inoperable due to irradiated fuel inoperable CRE boundary assemblies.

in MODE 5 or 6, or during movement of irradiated fuel assemblies.

G. Two CREFS trains G.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4, for reasons other than Condition B.

(continued)

PALO VERDE UNITS 1,2,3 3.7.11-2 AMENDMENT NO. 4-I-,4;4

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;
b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;
c. Quality assurance for effluent and environmental monitoring;
d. Fire Protection Program implementation; and
e. All programs specified in Specification 5.5.
f. Modification of core protection calculator (CPC) addressable constants. These procedures shall include provisions to ensure that sufficient margin is maintained in CPC type I addressable constants to avoid excessive operator interaction with CPCs during reactor operation.

Modifications to the CPC software (including changes of algorithms and fuel cycle specific data) shall be performed in accordance with the most recent version of the "Software Program Manual for Common Q Systems,", CE-CES-195,-which has been determined to be applicable to the facility. Additions or deletions to CPC addressable constants or changes to addressable constant software limit values shall not be implemented without prior NRC approval.

PALO VERDE UNITS 1,2,3 5.4-1 AMENDMENT NO. 4*-5, -ý

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.16 Containment Leakage Rate Testing Program (continued)

3. The first Type A test performed after the Unit 1 November 1999 Type A test shall be prior to November 4, 2014.
4. The first Type A test performed after the Unit 2 November 2000 Type A test shall be prior to November 2, 2015.
5. The first Type A test performed after the Unit 3 April 2000 Type A test shall be prior to April 27, 2015.
b. The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 52.0 psig for UnI 1 through9 operating cycle 12 and Unit 3 through operating cycle 13. and 58.0 psig for UnIt 1 a*ft opera.ting CyCle 1-2. Uln 2, and Unit 3 after operating -ycle 13. The containment design pressure is 60 psig.
c. The maximum allowable containment leakage rate, La, at Pa, shall be 0.1 % of containment air weight per day.
d. Leakage Rate acceptance criteria are:
1. Containment leakage rate acceptance criterion is
  • 1.0 La.

During the first unit startup following testing in accordance with this program, the leakage rate acceptance are < 0.60 La for the Type B and C tests and

  • 0.75 La for Type A tests.
2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is

  • 0.05 La when tested at Ž Pa.

b) For each door, leakage rate is

  • 0.01 La when pressurized to Ž 14.5 psig.
e. The provisions of SR 3.0.2 do not apply to the test frequencies in the Containment Leakage Rate Testing Program.
f. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

(continued)

PALO VERDE UNITS 1,2,3 5.5-16 AMENDMENT NO. 4774,-*-6

ATTACHMENT 2 Retyped Technical Specification Pages Pages:

3.3.1-7 3.3.2-5 3.3.5-4 3.3.9-1 3.3.9-2 3.5.5-3 3.7.11-2 5.4-1 5.5-16

RPS Instrumentation - Operating 3.3.1 Table 3.3.1-1 (page 1 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

1. Variable Over Power 1,2 SR 3.3.1.1 Ceiling
2. Logarithmic Power Level - High(a) 2 SR 3.3.1.1 < 0.011% NRTP SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13
3. Pressurizer Pressure - High 1.2 SR 3.3.1.1 2388 psia SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13
4. Pressurizer Pressure - Low 1.2 SR 3.3.1.1 1821 psia SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13
5. Containment Pressure High 1.2 SR 3.3.1.1 3.2 ps5g SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13
6. Steam Generator #1 Pressure - Low 1,2 SR 3.3.1.1 > 955 psia" SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13
7. Steam Generator #2 Pressure - Low 1.2 SR 3.3.1.1 n 955 psial" SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 (continued)

(a) Trip may be bypassed when logarithmic power is > IE-4% NRTP. Bypass shall be automatically removed when logarithmic power is ! IE-4% NRTP.

(aa) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band. then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value. the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point: otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance criteria band. and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3 3.3.1-7 AMENDMENT NO. 444

RPS Instrumentation - Shutdown 3.3.2 Table 3.3.2-1 Reactor Protective System Instrumentation - Shutdown APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALVE

1. Logarithmic Power Level-High(d) 3 (a). 4 a) 5(a) SR 3.3.2 1
  • 0.011% NRTP(C)

SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.4 SR 3.3.2.5

2. Steam Generator #1 Pressure-Low(b) 3 (a) SR 3.3.2.1 Ž955 psiae" SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.5
3. Steam Generator #2 Pressure-Low(b) 3 (a) SR 3.3.2.1 Ž955 psia"'

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.5 (a) With any Reactor Trip Circuit Breakers (RTCBs) closed and any control element assembly capable of being withdrawn.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained

  • 200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The setpoint must be reduced to < 1E-4% NRTP when less than 4 RCPs are running.

(d) Trip may be bypassed when logarithmic power is > IE-4% NRTP. Bypass shall be automatically removed when logarithmic power is

  • IE-4% NRTP.

(e) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point: otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint, 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3 3.3.2-5 AMENDMENT NO.

ESFAS Instrumentation 3.3.5 Table 3.3.5-1 (page 1 of 1)

Engineered Safety Features Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED FUNCTION CONDITIONS ALLOWABLE VALUE

1. Safety Injection Actuation Signal
a. Containment Pressure - High 1.2.3
  • 3.2 psig
b. Pressurizer Pressure - Low(a) > 1821 psia
2. Containment Spray Actuation Signal
a. Containment Pressure - High High 1.2.3 8B.9 psig
3. Containment Isolation Actuation Signal
a. Containment Pressure - High 1.2.3
  • 3.2 psig
b. Pressurizer Pressure - Low(a) > 1821 psia
4. Main Steam Isolation Signal(c)
a. Steam Generator #1 Pressure-Low(b) 1.2.3 Ž 955 psia"'
b. Steam Generator #2 Pressure-Low(b) Ž 955 psia"d
c. Steam Generator #1 Level-High
  • 91.5%
d. Steam Generator #2 Level-High
  • 91.5%
e. Containment Pressure-High < 3.2 psig
5. Recirculation Actuation Signal
a. Refueling Water Storage Tank Level-Low 1.2.3 > 9.15 and ! 9.65%1d)
6. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-1)
a. Steam Generator #1 Level-Low 1.2.3 Ž 25.3%
b. SG Pressure Difference-High  ! 192 psid
7. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2)
a. Steam Generator #2 Level-Low 1.2.3 Ž 25.3%
b. SG Pressure Difference-High
  • 192 psid (a) The setpoint may be decreased to a minimum value of 100 psia. as pressurizer pressure is reduced, provided the margin between pressurizer pressure and the setpoint is maintained
  • 400 psia or Ž 140 psia greater than the saturation pressure of the RCS cold leg when the RCS cold leg temperature is

Ž 485°F. Trips may be bypassed when pressurizer pressure is < 400 psia. Bypass shall be automatically removed when pressurizer pressure is Ž 500 psia. The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained

  • 200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The Main Steam Isolation Signal (MSIS) Function (Steam Generator Pressure - Low. Steam Generator Level-High and Containment Pressure - High signals) is not required to be OPERABLE when all associated valves isolated by the MSIS Function are closed.

(d) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band. then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint. or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point: otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3 3.3.5-4 AMENDMENT NO. 4432-

CREFAS 3.3.9 3.3 INSTRUMENTATION 3.3.9 Control Room Essential Filtration Actuation Signal (CREFAS)

LCO 3.3.9 One CREFAS channel shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CREFAS Manual Trip, A.1 Place one CREFS train 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Actuation Logic, or in essential radiation monitor filtration mode.

inoperable in MODE 1, 2, 3, or 4.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)

PALO VERDE UNITS 1.2,3 3.3.9-1 AMENDMENT NO. 4-14,

CREFAS 3.3.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. CREFAS Manual Trip, C.1 Place one CREFS train Immediately Actuation Logic, or in essential radiation monitor filtration mode.

inoperable in MODE 5 OR or 6, or during movement of irradiated C.2.1 Suspend movement of Immediately fuel assemblies. irradiated fuel assemblies.

AND Immediately C.2.2 Suspend positive reactivity additions.

Immediately AND C.2.3 Suspend CORE ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.9.1 Perform a CHANNEL CHECK on the required 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> control room radiation monitor channel.

(continued)

PALO VERDE UNITS 1,2,3 3.3.9-2 AMENDMENT NO. 14-ý,

RWT 3.5.5 634,000 GAL / 84.3% (565'F) 611,000 GAL /8 1.2% (210'F) K 650,000 85%9A 625.000 80%+ 600,000 575.000 uJ 75%-

550,000 c-Ix z

70%-.- 525,000 z 500.000

-J

'U t:6 cc 5 475.000

.'1

0. rW V i 0 0 100 200 300 400 500 600 AVERAGE RCS TEMPERATURE (OF)

FIGURE 3.5.5-1 Minimum Required RWT Volume PALO VERDE UNITS 1,2,3 3.5.5-3 AMENDMENT NO. -ýK

CREFS 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A or AND B not met in MODE 1, 2, C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> 3, or 4.

D. Required Action and D.1 Place OPERABLE Immediately associated Completion CREFS train in Time of Condition A not essential met in MODE 5 or 6. filtration mode.

E. Required Action and E.1 Place OPERABLE Immediately associated Completion CREFS Train in Time of Condition A not essential met during movement of filtration mode.

irradiated fuel OR assemblies. Immediately E.2 Suspend movement of irradiated fuel assemblies.

F. Two CREFS trains F.1 Suspend CORE Immediately inoperable in MODE 5 or ALTERATIONS.

6, or during movement of irradiated fuel AND assemblies.

OR F.2 Suspend movement of Immediately irradiated fuel One or more CREFS trains assemblies.

inoperable due to inoperable CRE boundary in MODE 5 or 6, or during movement of irradiated fuel assemblies.

G. Two CREFS trains G.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2,

3. or 4, for reasons other than Condition B.

(continued)

PALO VERDE UNITS 1,2.3 3.7.11-2 AMENDMENT NO. 4;4

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;
b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33:
c. Quality assurance for effluent and environmental monitoring;
d. Fire Protection Program implementation: and
e. All programs specified in Specification 5.5.
f. Modification of core protection calculator (CPC) addressable constants. These procedures shall include provisions to ensure that sufficient margin is maintained in CPC type I addressable constants to avoid excessive operator interaction with CPCs during reactor operation.

Modifications to the CPC software (including changes of algorithms and fuel cycle specific data) shall be performed in accordance with the most recent version of the "Software Program Manual for Common Q Systems," CE-CES-195, which has been determined to be applicable to the facility. Additions or deletions to CPC addressable constants or changes to addressable constant software limit values shall not be implemented without prior NRC approval.

PALO VERDE UNITS 1,2,3 5.4-1 AMENDMENT NO. ý-ý

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.16 Containment Leakage Rate Testing Program (continued)

3. The first Type A test performed after the Unit 1 November 1999 Type A test shall be prior to November 4, 2014.
4. The first Type A test performed after the Unit 2 November 2000 Type A test shall be prior to November 2, 2015.
5. The first Type A test performed after the Unit 3 April 2000 Type A test shall be prior to April 27, 2015.
b. The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 58.0 psig. The containment design pressure is 60 psig.
c. The maximum allowable containment leakage rate, La, at Pa, shall be 0.1 % of containment air weight per day.
d. Leakage Rate acceptance criteria are:
1. Containment leakage rate acceptance criterion is : 1.0 La.

During the first unit startup following testing in accordance with this program, the leakage rate acceptance are < 0.60 L, for the Type B and C tests and : 0.75 La for Type A tests.

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is

  • 0.05 La when tested at Ž Pa.

b) For each door, leakage rate is

  • 0.01 La when pressurized to Ž 14.5 psig.
e. The provisions of SR 3.0.2 do not apply to the test frequencies in the Containment Leakage Rate Testing Program.
f. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

(continued)

PALO VERDE UNITS 1,2,3 5.5-16 AMENDMENT NO. 4;-6

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