ML053220229
| ML053220229 | |
| Person / Time | |
|---|---|
| Site: | Palo Verde  |
| Issue date: | 11/16/2005 |
| From: | Fields M Plant Licensing Branch III-2 |
| To: | |
| Fields M B ,NRR/DLPM,415-3062 | |
| Shared Package | |
| ML053130286 | List: |
| References | |
| TAC MC3777, TAC MC3778, TAC MC3779 | |
| Download: ML053220229 (13) | |
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PVNGS Unit I Operating License Page 4 Retyped with Proposed Power Uprate Changes (6)(a) Pursuant to an Order of the Nuclear Regulatory Commission dated December 12, 1985, the Public Service Company of New Mexico (PNM) was authorized to transfer a portion of its ownership share in Palo Verde, Unit 1 to certain institutional investors on December 31, 1985, and at the same time has leased back from such purchasers the same interest in the Palo Verde, Unit 1 facility. The term of the lease is to January 15, 2015, subject to a right of renewal. Additional sale and leaseback transactions (for a term expiring on January 15, 2015) of all or a portion of PNM's remaining ownership share In Palo Verde Unit 1 are hereby authorized until June 30, 1987. Any such sale and leaseback transaction is subject to the representations and conditions set forth In the aforementioned applications of October 19, 1985, February 5,1986, October 16, 1986 and November 26, 1986, and the Commission's Order of December 12, 1985, consenting to such transactions. Specifically, the lessor and anyone else who may acquire an Interest under this transaction are prohibited from exercising directly or indirectly any control over the licensees of the Palo Verde Nuclear Generating Station, Unit 1. For purposes of this condition, the limitations In IOCFR 50.81, "Creditor Regulations," as now In effect and as they may be subsequently amended, are fully applicable to the lessor and any successor In Interest to that lessor as long as the license for Palo Verde, Unit 1 remains In effect; this financial transaction shall have no effect on the license for the Palo Verde nuclear facility throughout the term of the license.
(b) Further, the licensees are also required to notify the NRC in writing prior to any change in: (i) the terms or conditions of any lease agreements executed as part of this transaction; (ii) the ANPP Participation Agreement, (iii) the existing property Insurance coverage for the Palo Verde nuclear facility, Unit I as specified In license counsel's letter of November 26, 1985, and (iv) any action by the lessor or others that may have an adverse effect on the safe operation of the facility.
C.
This license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth In 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or Incorporated below:
(1)
Maximum Power Level Arizona Public Senrice Company (APS) is authorized to operate the facility at reactor core power levels not In excess of 3876 megawatts thermal (100% power) through operating cycle 12, and 3990 megawatts thermal (100% power) after operating cycle 12, in accordance with the conditions specified herein.
Amendment No. 4, 4G8, 429 157
PVNGS Unit 3 Operating License Page 4 Retyped with Proposed Power Uprate Changes
- (1)
Maximum Power Level Arizona Public Service Company (APS) is authorized to operate the facility at reactor core power levels not in excess of 3876 megawatts thermal (100% power) through operating cycle 13, and 3990 megawatts thermal (100% power) after operating cycle 13, in accordance with the conditions specified herein.
(2)
Technical Specifications and Environmental Protection Plan The Technical Specifications contained In Appendix A, as revised through Amendment No057, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated into this license.
APS shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.
(3)
Antitrust Conditions This license is subject to the antitrust conditions delineated In Appendix C to this license.
(4)
Initial Test Program (Section 14. SER and SSER 2)
Deleted (5)
Additional Conditions Deleted D.
APS has previously been granted an exemption from Paragraph 1ll.D.2(b)(ii) of Appendix J to 10 CFR Part 50. This exemption was previously granted in Facility Operating License NPF-65 pursuant to 10 CFR 50.12.
With the granting of this exemption, the facility will operate, to the extent authorized herein, in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission.
E.
The licensees shall fully Implement and maintain In effect all provisions of the Commission-approved physical security, guard training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The Safeguard Contingency Plan Is incorporated into the Physical Security Plan. The plans, which contain Safeguards Information protected under 10 CFR 73.21, are entitled: "Palo Amendment No. X, 83, 420, 4i2, 157
Definitions 1.1 1.1 Definitions (continued)
RATED THERMAL POWER (RTP)
REACTOR PROTECTIVE SYSTEM (RPS) RESPONSE TIME SHUTDOWN MARGIN (SDM)
RTP shall be a total reactor core heat transfer rate to the reactor coolant of 3876 MWt for Unit 1 through operating cycle 12 and Unit 3 through operating cycle 13. and 3990 MI~t for Unit 1 after operating cycle 12. Unit 2, and Unit 3 after operating cycle 13.
The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until electrical power to the CEAs drive mechanism is interrupted. The response time may be measured by means of any series of sequential. overlapping, or total steps so that the entire response time is measured.
In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.
SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:
- a. All full strength CEAs (shutdown and regulating) are fully inserted except for the single CEA of highest reactivity worth, which is assumed to be fully withdrawn. With any full strength CEAs not capable of being fully inserted. the withdrawn reactivity worth of these CEAs must be accounted for in the determination of SOM and
- b. There is no change in part length or part strength CEA position.
PALO VERDE UNITS 1,2,3 1.1-5 AMENDMENT NO. 4,
157 PALO VERDE UNITS 1,2,3 1.1-6 AMENDMENT NO. any", 157
RPS Instrumentation - Operating (Before CPC Upgrade) 3.3.1 rable 3.3.1-1 (page 1 of 3)
Reactor Protective System Instrumentation APPLICABLE MCGES OR OTHER SPECIFIED SURVEILLANCE FUNCTICN CONDITIONS RECUIREMEITS ALLOWABLE VALUE
- 1.
Variable Over Power 1.2
- 2. Logarithmic Power Level - High(d) 2
- 3. Pressurizer Pressure - High 1.2 SR 3.3.1.1 SR 3.3.1.4 SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.8 SR 3.3.1.9 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 Ceiling s 111.0: RIP Band S 9.9S RTP Incr. Rate s 11.0O/min RTP Decr. Rate > SS/sec RTP 5 0.011% NRTP s 2388 psla 2 1821 psia s 3.2 psig 3876 MWt RTP: 2 890 psia 3990 Wt RTP: 2 955 psia"11
- 4. Pressurizer Pressure - Low 1.2
- 5.
Containment Pressure - High 1.2
- 6. Steam Generator #1 Pressure - Low 1.2 I
- 7. Steam Generator #2 Pressure - Low 1.2 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 3876 Rdt RTP: > 890 psia 3990 MWt RTP: 2 9S5 psial"I I
(continued)
(a) rrip may be bypassed when logarithmic power Is > 1E.4:
when logarithmic power is s 1E-4t NRTP.
IIRTP.
Bypass shall be automatically removed (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 setpolnt 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 setpolnt tolerance band are specified in the UFSAR.
PALO VERDE UNITS 1.2.3 3.3.1-8 AMENDMENT NO. 1W, 157
RPS Instrumentation - Operating (After CPC Upgrade) 3.3.1 Table 3.3.1-1 (page 1 of 3)
Reactor Protective System Instrumentation APPL[CABLE mWOES OR OTHER SPECIFIED SURVEILLANCE FUNCTION COHDITIGNS REQUIREMENTS ALLOWABLE VALUE
- 1. Variable Over Power 1.2
- 2. Logarithmic Power Level - Hlgh(a) 2
- 3.
Pressurizer Pressure - High 1.2 SR 3.3.1.1 SR 3.3.1.4 SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.8 SR 3.3.1.9 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 Ceiling s 111.0S RTP Band s 9.9: RTP Incr. Rate S 11.0%/min RTP Decr. Rate - Stsec RTP s 0.011: NRTP s 2388 psia Z 1821 psia S 3.2 psig 3876 MWt RTP: 2 890 psia 3990 MWt RTP: 2 955 psia"&"
- 4.
Pressurizer Pressure -
Low 1.2
- 5.
Ccntainment Pressure - High 1.2
- 6. Steam Generator #1 Pressure - Low 1.2
- 7.
Stearn Generator #2 Pressure -
Low 1.2 SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 3876 MWt RTP: 2 890 psta 3990 MWIt RTP: 2 955 psiat"'
(continued)
(a) Trip may be bypassed when logarithmic power Is > 1E-4 MRTP.
Bypass shall when logarithmic power is S lE-4S NRTP.
be automatically removed (aa) 1. If the as-found charnel 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 functfoning 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 Setpolnt 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 tolerarce band are specified in the UFSAR.
PALO VERDE UNITS 1.2.3 3.3.1-17 AMENDMENT NO. 1, 157
RPS Instrumentation - Shutdown 3.3.2 Table 3.3.2-1 Reactor Protective System Instrumentation - Shutdown APPLICABLE MCOES OR OTHER SPECIFIED SURVEILLACE FUNCTION COMMIONIS RECUIREMENTS ALLOWABLE VALVE 1 Logarithmic Power Level-High(M 3(a). 4(a) 5ta)
SR 3.3.2.1 s 0.011% NRTPtc)
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 3876 MWt RTP: 2 890 psia SR 3.3.2.2 3990 MWt RTP: 2 955 psial" SR 3.3.2.4 SR 3.3.2.5
- 3. Steam Generator #2 Pressure-Low(b) 3da)
SR 3.3.2.1 3876 MWt RTP: 2 890 psia SR 3.3.2.2 3990 Mit RTP: a 955 psIa l
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 s 200 pslg.
The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.
(c)
The setpoint must be reduced to s 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 I 1E-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 AND 3 AMENDMENT NO. 4Ae. 157 PALO VERDE UNIT 2 3.3.2-5 AMENDMENT NO. 449, 157
ESFAS Instrumentation 3.3.5 Table 3.3.5-1 (page 1 of 1)
Engineered Safety Features Actuation System Instrumentation APPLICABLE MOOES OR OTHER SPECIFIED FUNCTION CONDITIONS ALLCMABLE VALUE
- 1. Safety Injection Actuation Signal
- a. Containment Pressure - High 1.2.3 s 3.2 psig
- b. Pressurizer Pressure - Low(a) a 3.21 psla
- 2. Containment Spray Actuation Signal
- a. Containment Pressure - High High 1.2.3 s 8.9 psig
- 3. Containrnnt Isolatiori Actuation Signal
- a.
Containment Pressure - Hiqh 1.2.3 s 3.2 psig
- b.
Pressurizer Pressure - Low a) a 1821 psla
- 4. Main Steam Isolation Signal(C)
- a. Steam Generator #i Pressure.Low(b) 1.2.3 3876 KWt RTP: 2 890 psia 3990 P4t RTP: 2 955 psia("'
- b.
Steam Generator #2 Pressure-Lcw(b) 3876 "At RTP: > 890 psia 3990 l14t RTP: 2 955 psial"'
- c.
Steam Generator #1 Level-High s 91.5?
- d.
Steam Generator #2 Level-High S 91.5?
- e. Containment Pressure-High s 3.2 psig
- 5. Recirculation Actuation Signal
- a.
Refueling Water Storage Tank Level-Low 1.2.3 2 6.9 and s 7.9:
- 6. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-1)
- a. Steam Generator #1 Level-Low 1.2.3 2 25.3?
- b.
SG Pressure Difference-High s 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 s 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 s 400 psia or 2 140 psia greater than the saturation pressure of the RCS cold leg when the RCS cold leg temperature is 2 4851F.
Trips may be bypassed when pressurizer pressure is < 400 psia.
Bypass shall be automatically removed when pressurizer pressure is 2 500 psia.
The setpoint shal1 be automatically increased to the normal setpolnt 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 s 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-round 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.
I PALO VERDE UNITS 1 AND 3 PALO VERDE UNIT 2 AMENDMENT NO.
i4-.
157 AMENDMENT NO.
-4. 157 3.3.5-4
RCS Pressure. TEmperature.
and Flow ONB Limits 3.4.1 Fi gure Reactor Cool ant Col d 3.4.1-1, (Page 1 of 2)
Leg Temperature vs. Core Power Level 3876 MWt RTP I
575 IL c
570
- 565 UJ 560 I-I q
555 V 550 545 540 575 570 565 560 555 550 545 540 0
10 20 30 40 50 60 70 80 90 CORE POWER LEV EL,%CF RATED THERMAL POWER (3875 MVmA) 100 PALO VERDE UNITS 1 AND 3 PALO VERDE UNIT 2 AMENDMENT NO.
44, 157 AMENDMENT NO. I, 157 3.4.1-3
RCS Pressure. Temperature. and Flow DNB Limits 3.4.1 Figure 3.4.1-1, (Page 2 of 2)
Reactor Coolant Cold Leg Temperature vs. Core Power Level 3990 M0lt RTP I
IL Er LU
-J w
w 575 570 565 560 I
I i
i I
I I
F (0,5;0)ZA 1C 575 570 565 560 555 550 555 550 545 545 540 rA r I
-,W I
I I
~ ~
I I
I
~ I I
0 10 20 30 40 50 60 70 80 90 CORE PONER LEVEL, % OF RAMED THERMAL POWER (3990 MA) 100 PALO VERDE UNITS 1 AND 3 PALO VERDE UNIT 2 AMENDMENT NO. a, 157 AMENDMENT NO.
, 157 3.4.1-4
MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)
Variable Overpower Trip Setpoint versus OPERABLE Main Steam Safety Valves MINIMUM NUMBER NUMBER OF MAXIMUM POWER MAXIMUM ALLOWABLE OF MSSVs PER INOPERABLE
(% RTP)
VARIABLE OVERPOWER TRIP STEAM GENERATOR MSSVs PER or HIGHEST MODE SETPOINT1a)
REQUIRED STEAM (A RTP)
OPERABLE GENERATOR 3876 MWt 3990 MWt 3876 MWt 3990 MWt RTP RTP RTP RTP 10 0
100.0 100.0 111.0 111.0 9
1 98.2 90.0 108.0 99.7 8
2 87.3 80.0 97.1 89.7 7
3 76.4 68.0 86.2 77.7 6
4 65.5 56.0 75.3 65.7 5
5 MODE 3 MODE 3 NA NA 4
6 MODE 3 MODE 3 NA NA 3
7 MODE 3 MODE 3 NA NA 2
8 MODE 3 MODE 3 NA NA I
(a) The VOPT setpoint is not required to be reset in MODE 3.
PALO VERDE UNITS 1. 2 AND 3 3.7.1-4 AMENDMENT NO.
155. 157
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.16 Containment Leakage Rate Testing Proqram (continued)
- b. The peak calculated containment internal pressure for the design basis loss of coolant accident. Pa. is 52.0 psig for Unit 1 through operating cycle 12 and Unit 3 through operating cycle 13. and 58.0 psig for Unit 1 after operating cycle 12. Unit 2. and Unit 3 after operating cycle 13.
The containment design pressure is 60 psig.
- c. The maximum allowable containment leakage rate. La. at Pa. shall be 0.1 Z 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 2 Pa-b)
For each door. leakage rate is
- 0.01 La when pressurized to 2 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 Leakage Rate Testing Program.
applicable to the Containment PALO VERDE UNITS 1.2,3 5.5-24 AMENDMENT NO. OAF, 157