ML20203F649
| ML20203F649 | |
| Person / Time | |
|---|---|
| Site: | Vogtle  |
| Issue date: | 02/08/1999 |
| From: | Berkow H Office of Nuclear Reactor Regulation |
| To: | Southern Nuclear Operating Co, Georgia Power Co, Oglethorpe Power Corp, Municipal Electric Authority of Georgia, City of Dalton, GA |
| Shared Package | |
| ML20203F656 | List: |
| References | |
| NPF-68-A-106, NPF-81-A-084 NUDOCS 9902180242 | |
| Download: ML20203F649 (15) | |
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UNITED STATES 3
j NUCLEAR REGULATORY COMMISSION i
f WASHINGTON, D.C. 20565-0001 o,s...../
i SOUTHERN NUCLEAR OPERATING COMPANY. INC.
GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DALTON. GEORGIA VOGTLE ELECTRIC GENERATING PLANT. UNIT 1 AMENDMENT TO FACILITY OPERATING LICENSE 4
Amendment No.106 License No. NPF-68
- 1. The Nuclear Regulatory Commission (the Commission) has found that:
4 A. The application for amendment to the Vogtle Electric Generating Plant, Unit 1 (the facility) Facility Operating License No. NPF-68 filed by the Southern Nuclear Operating Company, Inc. (Southern Nuclear), acting for itself, Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia (the licensees), dated July 13,1998, as supplemented by letters dated December 16,1998, and January 13,1999, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can l
be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and l
E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
9902180242 990208 PDR ADOCK 05000424 P
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- 2. Accordingly, the license is hereby amended by page changes to the Technical Spe:ifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-68 is hereby amended to read as follows:
Technical Soecifications and Environmental Protection Plan i
l The Technical Specifications contained in Appendix A, as revised through Amendment No. 106, and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license. Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
- 3. This license amendment is effective as of its date of issuance and shall be implemented within 30 days from the date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION i
rbert N. Berkow, Director Project Directorate 11-2 Division of Reactor Projects - 1/11 Office of Nuclear Reactor Regulation
Attachment:
j Technical Specification Changes Date of issuance: February 8, 1999 l
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UNITED STATES E
j NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20ee6-0001
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SOUTHERN NUCLEAR OPERATING COMPANY. INC.
GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DALTON. OEORGIA VOGTLE ELECTRIC GENERATING PLANT. UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 84 License No. NPF-81
- 1. The Nuclear Regulatory Commission (the Commission) has found that:
A. The application for amendment to the Vogtle Electric Generating Plant, Unit 2 (the facility) Facility Operating License No. NPF-81 filed by the Southern Nuclear Operating Company, Inc. (Southern Nuclear), acting for itself, Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia (the licensees), dated July 13,1998, as supplemented by letters dated December 16,1998, and January 13,1999, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisior.s of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
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- 2. Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-81 is hereby amended to read as follows:
Technical Soecifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 84, and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license.
Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
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- 3. This license amendment is effective as of its date of issuance and shall be implemented within 30 days from the date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION 1
/-
rbert N. Berkow, Director Project Directorate ll 2 Division of Reactor Projects - t/11 Office of Nuclear Reactor Regulation
Attachment:
Technical Specification Changes Date of issuance: February 6, 1999 l
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ATTACHMENT TO LICENSE AMENDMENT NO.i nn FACILITY OPERATING LICENSE NO. NPF-68 DOCKET NO. 50-424 AN_Q TO LICENSE AMENDMENT NO. Aa FACILITY OPERATING LICENSE NO. NPF-81 DOCKET NO. 50-425 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain verticallines indicating the areas of change.
Remove jnggrt 1.1-3 1.1-3 1.1-5 1.1 -5 B 3.3-59 B 3.3-59 B 3.3-59a*
B 3.3-59b" B 3.3-60 B 3.3-60 8 3.3-108 B 3.3-108 B 3.3-108a B 3.3-108b" B 3.3-109a B 3.3-109a
- no changes - overflow "intentionallyleft blank l
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Definitions 1.1 1.1 Definitions (continued)
G - AVERAGE E shall be the average the concentration of eac(h radionuclide in theweighted in proportio DISINTEGRATION ENERGY reactor coolant at the time of sampling disintegration (ge beta and gamma energ? o sum of the avera oes per iodines, with half live)s > 14 minutes, making up in MeV for isotopes, other than at least 95% of the total noniodine activity in the coolant.
ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time FEATURE (ESF) RESPONSE interval from when the monitored TIME parameter exceeds its ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e.
the positlons,valvestraveltotheirrequired pump dischar required values, etc.l.ge pressures reach their Times shall include diesel generator starhing and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.
In lieu of measurement, response time may be verified for selected components provided that the components and the methodology for verification have been previously reviewed and approved by the NRC.
LEAKAGE LEAKAGE shall be:
a.
Identified LEAKAGE 1.
LEAKAGE such as that from pump seals or valve pa,cking (except reactor coolant pump that)is captured and conducted toseal water injection i
(RCP collection systems or a sump or collecting tank; 2.
LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or 3.
Reactor Coolant System (RCS) LEAKAGE through a steam generator (SG) to the Secondary System; (continued) 2 Vogtle Units 1 and 2 1.1-3 Amendment No.106 (Unit 1)
Amendment No. 84 (Unit 2)
-. _ _ _ _ _ _ _. _. ~ _ _
Definitions 1.1 1.1 Definitions
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' PHYSICS TESTS a.
Described in Chapter 14 of the FSAR; l
(continued) b.
Authorized under the provisions of 10 CFR 50.59; or c.
Otherwise approved by the Nuclear Regulatory Commission.
)
PRESSURE AND The PTLR is the unit specific document that TEMPERATURE LIMITS provides the reactor vessel pressure and l
REPORT (PTLR) temperature limits, including heatup and cooldown rates and the nominal PORV setpoints for the cold
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overpressure protection system, for the current reactor vessel fluence period. Tnese pressure and i
temperature limits shall be determined for each fluence period in accordance with Specification 5.6.6.
Unit operation within these operating limits is addressed in individual specifications.
l QUADRANT POWER TILT QPTR shall be the ratio of the maximum upper RATIO (QPTR) excore detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.
I RATED THERMAL POWER RTP shall be a total reactor core heat transfer l
L (RTP) rate to the reactor coolant of 3565 MWt.
REACTOR ~ TRIP The RTS RESPONSE TIME shall be that time interval SYSTEM-(RTS) RESPONSE from when the monitored parameter TIME exceeds its RTS trip setpoint at the channel sensor until loss of stationary gripper coil voltage. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.
In lieu of measurement, response time may be verified for selected components provided that the components and the methodology for i
verification have been previously reviewed and i
l approved by the NRC.
I i-j (continued)
Vogtle Units 1 and 2 1.1-5 Amendment No.106(Unit 1)
Amendment No. 84(Unit 2)
RTS Instrumentation l
B 3.3.1
-BASES SURVEILLANCE SR 3.3.1.15 (continued)
REQUIREMENTS.
calculated assuming the time constants are set at their nominal values. The response time may be measured by a
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series of overlapping tests such that the entire response time is measured.
Response' time may be verified by actual response time tests in any series of sequential, overlapping'or total channel measurements, or by the summation of allocated sensor, signal processing and actuation logic response times with actual response time tests on the remainder of the channel.
i Allocations for sensor response times may be obtained from:
(1) historical records based on acceptable response time tests (hydraulic, noise, or power interrupt tests), (2) in place, onsite, or offsite (e.g., vendor) test measurements, or (3) utilizing vendor engineering specifications. WCAP-13632-P-A Revision 2, " Elimination of Pressure Sensor Response Time Testing Requirements," provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the WCAP. Response time verification for other sensor types must be demonstrated by test.
WCAP-14036-P Revision 1
" Elimination of Periodic Protection Channel Response Time Tests," provides the basis ~and methodology for using allocated signal processing and actuation logic-response times in the overall_ verification 4
of the protection. system channel response time. The I
allocations for sensor, signal conditioning and actuation i
logic response times must be verified prior to placing the component in operational service and re-verified following maintenance that may adversely affect response time.
In general, electrical repair work does not impact response
~ time provided the parts used for repair are of the same type and value.
Specific components identified in the WCAP may be replaced without verification testing. One example where response time could be affected is replacing the sensing assembly of a transmitter.
As appropriate, each channel's response must be verified every 18 months on a STAGGERED TEST BASIS. Testing of the final actuation devices is included in the testing.
Response times cannot be determined during unit operation because equipment operation is required to measure response (continued)
Vogtle Units 1 and 2 B 3.3-59 Amendmd W N5i 106 (Unit 1)
Amendment No. 84 (Unit 2)
RTS Instrumentation B 3.3.1 1
BASES SURVEILLANCE SR 3.3.1.15 (continued)
REQUIREMENTS times.
Experience has shown that these components usually pass this surveillance when performed at the 18 month t
Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
l SR 3.3.1.15 is modified by a Note stating that neutron detectors are excluded from RTS RESPONSE TIME testing. This Note is necessary because of the difficulty in generating an appropriate detector input signal.
Excluding the detectors is acceptable because the principles of detector operation ensure a virtually instantaneous response.
I SR 3.3.1.16 SR 3.3.1.16 is the performance of a COT for the ' low fluid oil pressure portion of the Turbine Trip Functions as described in SR 3.3.1.7 except that the Frequency is after each entry into MODE 3 for a unit shutdown and prior to exceeding the P-9 interlock trip setpoint. The surveillance is modified by two Notes. Note I states that the surveillance may be satisfied if performed within the l
previous 31 days. Note 2 states that verification of the setpoint is not required. The Frequency ensures that the turbine trip on low fluid oil pressure channels is OPERABLE l
after each unit shutdown and prior to entering the Mode of Applicability (above the P-9 power range neutron flux interlock) for this instrument function.
REFERENCES 1.
FSAR, Chapter 7.
(continued) l i
Amendment'!o.84(fnit2j)l Amendment NO. -106 Unit l
Vogtle Units 1 and 2 B 3.3-59a l
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RTS In.strumentation B 3.3.1 BASES i
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(continued)
Vogtle Units 1 and 2 B 3.3-59b Amendment No.106 tuni t 1) l Amendment No. 84 (Unit 2) 1.
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RTS Instrumentation B 3.3.1 BASES REFERENCES (continued) 2.
FSAR, Chapter 6.
3.
FSAR, Chapter 15.
4.
5.
6.
WCAP-11269, Westinghouse Setpoint Methodology for Protection Systems; as supplemented by:
Amendments 34 (Unit 1) and 14 (Unit 2), RTS Steam Generator Water Level - Low Low, ESFAS Turbine Trip and Feedwater Isolation SG Water Level - High High, and ESFAS AFW SG Water Level - Low Low.
Amendments 48 and 49 (Unit 1) and Amendments 27 and 28 (Unit 2), deletion of RTS Power Range Neutron Flux High Negative Rate Trip.
Amendments 60 (Unit 1) and 39 (Unit 2), RTS Overtemperature AT setpoint revision.
Amendments 57 (Unit 1) and 36 (Unit 2), RTS Overtemperature and Overpower AT time constants and Overtehiperature AT setpoint.
Amendments 43 and 44 (Unit 1) and 23 and 24 (Unit 2), revised Overtemperature and Overpower AT trip setpoints and allowable values.
7.
WCAP-10271-P-A, Supplement 2, Rev.1, June 1990.
8.
FSAR, Chapter 16.
9.
Westinghouse Letter GP-16696, November 5, 1997.
- 10. WCAP-13632-P-A Revision 2, " Elimination of Pressure Sensor Response Time Testing Requirements," January 1996.
II. WCAP-14036-P-A Revision 1, " Elimination of Periodic Protection Channel Response Time Tests," October 1998.
Vogtle Units I and 2 B 3.3-60 Amendment No. 106 (U'it 1) n Amendment No. 84 (Unit 2)
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ESFAS Instrumentatien i
B 3.3.2 i
BASES I
SURVEILLANCE-SR 3.3.2.7 (continued)
REQUIREMENTS The Frequency of 18 months is based on the assumption of an
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18 month calibration interval in the determination of the magnitude of equipment drift in the setpoint methodology.
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This SR is odified by a Note stating that this test should include verification that the time constants are adjusted to the prescribed values where applicable. The steam line pressure-low and steam line pressure negative rate-high functions have time constants specified in their setpoints.
SR 3.3.2.8 This SR ensures the individual channel ESF RESPONSE TIMES are less than or equal to the maximum values assumed in the accident analysis. Response Time testing acceptance criteria are included in the FSAR, Chapter 16 (Ref. 8).
Individual component response times are not modeled in the j
analyses. The analyses model the overall or total elapsed i
time, from the point at which the parameter exceeds the Trip Setpoint value at the sensor, to the point at which the equipment in both trains reaches the required functional state (e.g., pumps at rated discharge pressure, valves in full open or closed position).
For channels that include dynamic transfer functions (e.g.,
lag, lead / lag, rate / lag, etc.), the response time test may be perfomed with the transfer functions set to one with the resulting measured response time compared to the appropriate FSAR response time. Alternately, the response time test can be performed with the time constants set to their nominal value provided the required response time is analytically calculated assuming the time constants are set at their nominal. values. The response time may be measured by a series of overlapping tests such that the entire response time is measured.
Response time may be verified by actual response time tests in any series of sequential, overlapping or total channel measurements, or by the summation of allocated sensor, signal processing and actuation logic response times with actual response time tests on the remainder of the channel.
Allocations for sensor response times may be obtained from:
(continued)
Vogtle Units 1 and 2 8.3.3-108 Amendment No. 106 (Unit 1)
Amendment No. 84 (Unit 2)
ESFAS Instrumentation B 3.3.2 i
BASES SURVEILLANCE SR 3.3.2.8 (continued)
REQUIREMENTS (1) historical records based on acceptable response time tests (hydraulic, noise, or power interrupt tests), (2) inplace, onsite, or offsite (e.g., vendor).. test measurements,-.or (3) utilizing vendor engineering i
specifications.. WCAP-13632-P-A Revision 2. " Elimination' of Pressure Sensor Response Time Testing Requirements,"
provides the basis and methodology for using allocated sensor response times in the overall verification of the j
channel response time for specific sensors identified in the i
WCAP. Response time verification for other sensor types must be demonstrated by test.
WCAP-14036-P Revision 1, " Elimination of Periodic Protection Channel Response Time Tests," provides the basis and l
methodology for using allocated signal processing and actuation logic response times in the overall verification of the protection system channel response time. The allocations for sensor, signal conditioning and' actuation logic response times must be verified prior to placing the component in operational service and re-verified following maintenance that may adversely affect response time.
In general, electrical repair work does not impact response time provided the parts used for repair are of the same type and value.- Specific components identified in the WCAP may j
be replaced without verification testing. One example where response time could be affected is replacing the sensing assembly of a transmitter.
ESF RESPONSE TIME tests are conducted on an 18 month STAGGERED TEST BASIS. Testing of the final actuation devices, which 'make up the bulk of the 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 i
(continued) l t
Vogtle Units 1 and 2 8 3.3-108a Amendment No.106 (Unit 1) l Amendment No. 84 (Unit 2) 4
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ESFAS Instrumentatien l
8 3.3.2 c
BASES i
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Vogtle Units 1 and 2 B 3.3-108b Amendment No.106 (Unit 1) l Amendment No. 84 (Unit 2)
ESFAS Instrumentation B 3.3.2 i
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BASES REFERENCES (continued)
Amendments 43 and 44 (Unit 1) and 23 and 24 (Unit 2), revised ESFAS Interlocks Pressurizer P-11 trip setpoint and allowable value.
7.
WCAP-10271-P-A, Supplement 2, Rev. 1, June 1990.
l 8.
FSAR, Chapter 16.
i 9.
Westinghouse Letter GP-16696, November 5, 1997.
- 10. WCAP-13632-P-A Revision 2, " Elimination of Pressure Sensor Response Time Testing Requirements," January 1996.
- 11. WCAP-14036-P-A Revision 1, " Elimination of Periodic Protection Channel Response Time Tests," October 1998.
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Vogtle Units I and 2 B 3.3-109a Amendment No. 106 (Ilnit 1)
Amendment No. 84 (Unit 2) i