ML12340A068
| ML12340A068 | |
| Person / Time | |
|---|---|
| Site: | McGuire, Mcguire  |
| Issue date: | 11/07/2012 |
| From: | Beaver B Duke Energy Carolinas |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| DUK123120034 | |
| Download: ML12340A068 (51) | |
Text
PRIORITY Normal DISPOSITION OF THE ORIGINAL DOCUMENT WILL BE TO THE TRANSMITTAL SIGNATURE UNLESS RECIPIENT IS OTHERWISE IDENTIFIED BELOW
- 1) 01820 J R ELKINS-EC081
- 2) 02388 BOB SCHOMAKER LYNCHBG, VA
- 3) 02532 RESIDENT NRC INSPECT MG01NRC
- 4) 02546 WC LIBRARY-MG01WC
- 5) 03044 MCG DOC CNTRL MISC MAN MG05DM
- 8) 03744 OPS TRNG MGR. MG03OT
- 9) 03759 U S NUC REG WASHINGTON, DC
- 10) 03796 SCIENTECH CLEARWTR, FL
- 11) 04698 D E BORTZ EC08G
- 12) 04809 MCG PLANT ENG. LIBR. MG05SE
- 13) 05262 J L FREEZE MG01IE
- 14) 05606 J C MORTON MG01EP
- 15) 08103 WESTINGHOUSE ELECTRIC CO LLC Duke Energy DOCUMENT TRANSMITTAL FORM REFERENCE MCGUIRE NUCLEAR STATION RECORD RETENTION # 698650 TECHNICAL SPEC (TS)
Page 2 of 3 Date:
11/07/12 Document Transmittal #:
DUK123120034 QA CONDITION
[: Yes
- No OTHER ACKNOWLEDGEMENT REQUIRED
Duke Energy McGuire DCRM MGO2DM 13225 Hagers Ferry Road Huntersville, N.C.
28078 Rec'd By Date DOCUMENT NO QACOND REV #/DATE DISTR CODE 1
2 3
4 5
6 7
8 9
10 11 12 13 14 15 TOTAL MEMO 1 PAGE UNIT#1 FOL 13 PAGES UNIT#2FOL 13 PAGES TS LIST OF EFFECTIVE PAGES 11 PAGES TS 1.1 P2 266/246 1 PAGE TS 3.4.16 P 1 & 2 2 PAGES TSB LIST OF EFFECTIVE SECTIONS 4 PAGES BASES 3.4.16 5 PAGES NA NA NA NA NA NA NA NA 10/19/12
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--- 10/19/12 MADM-04B vl vi V3 vi vi V1 V1 31 REMARKS:
PLEASE UPDATE ACCORDINGLY S D CAPPS VICE PRESIDENT MCGUIRE NUCLEAR STATION BY:
B C BEAVER MGO1RC BCB/TLC A
October 19, 2012 MEMORANDUM To: All McGuire Nuclear Station Technical Specification (TS) and Tech Spec Bases (TSB) Manual Holders
Subject:
McGuire TS and TSB Updates Attention: Facility Operating License (FOL) Included Included in this distribution is an updated copy of the Unit I and Unit 2 FOL. Please place the updated copies in the front of your Technical Specification book. Please recycle your old copies. The FOL was updated to reflect Amendment 266/246.
REMOVE TS Manual INSERT TS LOEP (Revision 92)
TS 1.1 (Page 2)
TS 3.4.16 (Pages I and 2)
TS LOEP (Revision 93)
TS 1.1 (Page 2)
Amendment 266/246 TS 3.4.16 (Pages 1 and 2)
Amendment 266/246 TS Bases Manual TSB LOES (Revision I 11)
TSB 3.4.16 - Entire Section TSB LOES (Revision 112)
TSB 3.4.16 - Entire Section (Rev 121)
Revision numbers may skip numbers due to Regulatory Compliance Filing System.
Please call me if you have questions.
.Bonnie Beaver Regulatory Compliance 875-4180
DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-369 MCGUIRE NUCLEAR STATION, UNIT 1 RENEWED FACILITY OPERATING LICENSE Renewed License No.-NPF-9
- 1.
The U.S. Nuclear Regulatory Commission (Commission), having previously made the findings set forth in License No. NPF-9 issued on June 12, 1981, has now found that:
A.
The application for renewed operating license filed by the Duke Energy Corporation* complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I and all required notifications to other agencies or bodies have been duly made; B.
Actions have been identified and have been or will be taken with respect to (1) managing the effects of aging during the period of extended operation on the functionality of structures and components that have been identified to require review under 10 CFR 54.21(a)(1), and (2) time-limited aging analyses that have been identified to require review under 10 CFR 54.21 (c), such that there is reasonable assurance that the activities authorized by the renewed operating license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for the McGuire Nuclear Station, Unit 1 (facility or plant), and that any changes made to the plant's current licensing basis in order to comply with 10 CFR 54.29(a) are in accord with the Act and the Commission's regulations; C.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission; D.
There is reasonable assurance: (i) that the activities authorized by this renewed operating license 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; E.
The licensee is technically and financially qualified to engage in the activities authorized by this renewed operating license in accordance with the Commission's regulations set forth in 10 CFR Chapter I; Duke Energy Corporation converted to Duke Power Company LLC on April 3, 2006 and was re-named Duke Energy Carolinas, LLC as of October 1, 2006. Duke Energy Carolinas, LLC is the owner and operator of McGuire Nuclear Station, Unit 1. References to the "licensee" or "Duke" are to Duke Energy Carolinas, LLC.
Renewed License No. NPF-9 Amendment No. 245 F.
The licensee has satisfied the applicable provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; G.
The issuance of this renewed operating license will not be inimical to the common defense and security or to the health and safety of the public; H.
After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of this Renewed Facility Operating License No. NFP-9 is in accordance with 10 CFR Part 51, of the Commission's regulations and all applicable requirements have been satisfied; and, I. The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this renewed operating license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40 and 70.
- 2.
Based on the foregoing findings, and pursuant to approval by the Nuclear Regulatory Commission at a meeting on June 9, 1981, the License for Fuel-Loading and Zero Power Testing issued on January 23, 1981, as amended, is superseded by Renewed Facility Operating License No. NPF-9 which is hereby issued to Duke Energy Carolinas, LLC to read as follows:
A.
This renewed operating license applies to the McGuire Nuclear Station, Unit 1, a pressurized water reactor and associated equipment (the facility) owned and operated by Duke Energy Carolinas, LLC. The facility is located on the licensee's site in Mecklenburg County, North.Carolina, on the shore of Lake Norman approximately 17 miles northwest of Charlotte, North Carolina and is described in the Updated Final Safety Analysis Report, as supplemented and amended, and in the Environmental Report, as supplemented and amended.
B.
Subject to the conditions and requirements incorporated herein, the Commission hereby licenses Duke Energy Carolinas, LLC:
(1)
Pursuant to Section 103 of the Act and 10 CFR Part 50, to possess, use, and operate the facility at the designated location in Mecklenburg County, North Carolina, in accordance with the procedures and limitations set forth in the renewed operating license; (2)
Pursuant to the Act and 10 CFR Part 70 to receive, possess and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Updated Final Safety Analysis Report, as supplemented and amended; (3)
Pursuant to the Act and 10 CFR Parts 30, 40 and 70 to receive, possess and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; Renewed License No. NPF-9 Amendment No. 245 (4)
Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; (5)
Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to possess, but not separate, such byproducts and special nuclear materials as may be produced by the operation of McGuire Nuclear Station, Units 1 and 2, and; (6)
Pursuant to the Act and 10 CFR Parts 30 and 40, to receive, possess and process for release or transfer such byproduct material as may be produced by the Duke Training and Technology Center.
C.
This renewed operating 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 The licensee is authorized to operate the facility at a reactor core full steady state power level of 3411 megawatts thermal (100%).
(2)
Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 266, are hereby incorporated into this renewed operating license. The licensee shall operate the facility in accordance with the Technical Specifications.
(3)
Updated Final Safety Analysis Report The Updated Final Safety Analysis Report supplement submitted pursuant to 10 CFR 54.21(d), as revised on December 16, 2002, describes certain future activities to be completed before the period of extended operation.
Duke shall complete these activities no later than June 12, 2021, and shall notify the NRC in writing when implementation of these activities is complete and can be verified by NRC inspection.
The Updated Final Safety Analysis Report supplement as revised on December 16, 2002, described above, shall be included in the next scheduled update to the Updated Final Safety Analysis Report required by 10 CFR 50.71(e)(4), following issuance of this renewed operating license.
Until that update is complete, Duke may make changes to the programs described in such supplement without prior Commission approval, provided that Duke evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.
Renewed License No. NPF-9 Amendment No. 266 (4)
Fire Protection Program Duke Energy Carolinas, LLC shall implement and maintain in effect all provisions of the approved fire protection program as described in the Updated Final Safety Analysis Report for the facility and as approved in the SER dated March 1978 and Supplements 2, 5 and 6 dated March 1979, April 1981, and February 1983, respectively, and the safety evaluation dated May 15, 1989, subject to the following provision:
Duke may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.
(5)
Additional Conditions The Additional Conditions contained in Appendix B, as revised through Amendment No. 200, are hereby incorporated into this renewed operating license. Duke Energy Carolinas, LLC shall operate the facility in accordance with the Additional Conditions.
(6)
Antitrust Conditions The licensee shall comply with the antitrust conditions delineated in Appendix C of this renewed operating license.
(7)
Mitigation Strategy License Condition Develop and maintain strategies for addressing large fires and explosions and that include the following key areas:
A)
Fire fighting response strategy with the following elements:
- 1.
Pre-defined coordinated fire response strategy and guidance
- 2.
Assessment of mutual aid fire fighting assets
- 3.
Designated staging areas for equipment and materials
- 4.
Command and control
- 5.
Training of response personnel B)
Operations to mitigate fuel damage considering the following:
- 1.
Protection and use of personnel assets
- 2.
Communications
- 3.
Minimizing fire spread
- 4.
Procedures for implementing integrated fire response strategy
- 5.
Identification of readily-available pre-staged equipment
- 6.
Training on integrated fire response strategy
- 7.
Spent fuel pool mitigation measures C)
Actions to minimize release to include consideration of:
- 1.
Water spray scrubbing
- 2.
Dose to onsite responders Renewed License No. NPF-9 Amendment No. 264
-4A-D.
Physical Protection Duke Energy Carolinas, LLC shall fully implement and maintain in effect all provisions of the Commission-approved physical security, 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 combined set of plans, which contains safeguards information protected under 10 CFR 73.21, is entitled: "Duke Energy Physical Security Plan" submitted by letter dated September 8, 2004, and supplemented on September 30, 2004, October 15, 2004, October 21, 2004, and October 27, 2004.
Duke Energy Carolinas, LLC shall fully implement and maintain in effect all provisions of the Commission-approved cyber security plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p).
The Duke Energy Carolinas, LLC CSP was approved by License Amendment No. 264.
E.
Deleted by Amendment No. 233.
Renewed License No. NPF-9 Amendment No. 264 F.
The licensee shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.
G.
The licensee is authorized to receive from the Oconee Nuclear Station, Units 1, 2, and 3, possess, and store irradiated Oconee fuel assemblies containing special nuclear material, enriched to not more than 3.24% by weight U-235 subject to the following conditions:
- a. Oconee fuel assemblies may not be placed in the McGuire Nuclear Station, Unit 1 and 2, reactors.
- b. Irradiated fuel shipped to McGuire Nuclear Station, Units 1 and 2, from Oconee shall have been removed from the Oconee reactor no less than 270 days prior to shipment.
- c. No more than 300 Oconee irradiated fuel assemblies shall be received for storage at McGuire Nuclear Station.
- d. Burnup of Oconee fuel shipped shall be no greater than 36,000 MW days per metric ton.
- e. Receipt of irradiated Oconee fuel shall be limited by the use of the NFS-4 (NAC-1), NLI-1/2, TN-8, or TN-8L spent fuel casks.
- f.
The spent fuel pool crane travel shall be restricted by administrative controls to the paths required by Selected Licensee Commitment 16.9.20 whenever a spent fuel cask is being handled.
- g. Oconee fuel assemblies may not be transferred from one McGuire spent fuel pool to the other.
- 3. This renewed operating license is effective as of the date of issuance and shall expire at midnight on June 12, 2041.
FOR THE NUCLEAR REGULATORY COMMISSION J.E. Dyer, Director Office of Nuclear Reactor Regulation
Attachment:
- 1. Appendix A - Technical Specifications
- 2. Appendix B - Additional Conditions
- 3. Appendix C - Antitrust Conditions Date of Issuance: December 5, 2003 Renewed License No. NPF-9
APPENDIX B ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-9 Duke Energy Carolinas, LLC shall comply with the following conditions on the schedules noted below:
Amendment Additional Implementation Number Conditions Date 184 The schedule for the performance of new and Within 90 days of revised surveillance requirements shall be as the date of this follows:
amendment.
For surveillance requirements (SRs) that are new in Amendment No. 184 the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment No. 184. For SRs that existing prior to Amendment No. 184, including SRs with modified acceptance criteria and SRs whose intervals of performance are being extended, the first performance is due at the end of the first surveillance interval that begins on the date the surveillance was last performed prior to implementation of amendment No. 184. For SRs that existed prior to Amendment No. 184, whose intervals of performance are being reduced, the first reduced surveillance interval begins upon completion of the first surveillance performed after implementation of Amendment No. 184.
Renewed License No. NPF-9 Amendment No. 258
-B1-
APPENDIX B ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-9 Duke Power Power Company LLC shall comply with the following conditions on the schedules noted below:
Amendment Additional Implementation Number Conditions Date 249 Upon implementation of the Amendment adopting TSTF-See Condition 448, Revision 3, the determination of control room envelope (CRE) unfiltered inleakage as required by SR 3.7.9.4, in accordance with TS 5.5.16.c.(i), the assessment of CRE habitability as required by TS 5.5.16.c.(ii), and the measurement of CRE pressure as required by TS 5.5.16.d, shall be considered met.
Following implementation:
(a) The first performance of SR 3.7.9.4 in accordance with TS 5.5.16.c.(i), shall be within the specified Frequency of 6 years, plus the 18 month allowance of SR 3.0.2, as measured from October 2003, the date of the most recent successful tracer gas test, as stated in the February 19, 2004 letter response to Generic Letter 2003-01, or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.
(b) The first performance of the periodic assessment of CRE habitability, TS 5.5.16.c.(ii), shall be within 3 years, plus the 9 month allowance of SR 3.0.2 as measured from October 2003, the date of the most recent successful tracer gas test, as stated in the February 19, 2004 letter response to Generic Letter 2003-01, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.
(c) The first performance of the periodic measurement of CRE pressure, TS 5.5.16.d, shall be within 18 months, plus the 138 days allowed by SR 3.0.2, as measured from January 2007, the date of the most recent successful pressure measurement test, or within 138 days if not performed previously.
Renewed License No. NPF-9 Amendment No. 249 B-2
APPENDIX C ANTITRUST CONDITIONS Pursuant to an Order by the Atomic Safety and Licensing Board, dated April 23, 1975, the Nuclear Regulatory Commission incorporates in Renewed Operating License NPF-9 the following antitrust conditions:
- a. The licensee makes the commitments contained herein, recognizing that bulk power supply arrangements between neighboring entities normally tend to serve the public interest. In addition, where there are net benefits to all participants such arrangements also serve the best interests of each of the participants.
Among the benefits of such transactions are increased electric system reliability, a reduction in the cost of electric power, and minimization of the environmental effects of the production and sale of electricity.
Any particular bulk power supply transaction may afford greater benefits to one participant than to another. The benefits realized by a small system may be proportionately greater than those realized by a larger system. The relative benefits to be derived by the parties from a proposed transaction, however, should not be controlling upon a decision with respect to the desirability of participating in the transaction. Accordingly, the licensee will enter into proposed bulk power transactions of the types hereinafter described which, on balance, provide net benefits to the licensee. There are net benefits in a transaction if the licensee recovers the cost of the transaction, (as defined in subparagraph (1)(d) hereof) and there is no demonstrable net detriment to the licensee arising from the transaction.
(1)
As used herein:
(a)
"Bulk Power" means electric power and any attendant energy, supplied or made available at transmission or sub-transmission voltage by one electric system to another.
(b)
"Neighboring Entity" means a private or public corporation, a governmental agency or authority, a municipality, a cooperative, or a lawful association of any of the foregoing owning or operating, or proposing to own or operate, facilities for the generation and transmission of electricity which meets each of the following criteria:
(1) its existing or proposed facilities are economically and technically feasible of interconnection with those of the licensee and (2) with the exception of municipalities, cooperatives, governmental agencies or authorities, and associations, it is, or upon commencement of operations will be, a public utility and subject to regulation with respect to rates and service under the laws of North Carolina or South Carolina or under the Federal Power Act; provided, however, that as to associations, each member of such association is either a public utility as discussed in this clause (2) or a municipality, a cooperative or C-1
a governmental agency or authority.
(c)
Where the phrase "neighboring entity" is intended to include entities engaging or proposing to engage only in the distribution of electricity, this is indicated by adding the phrase "including distribution systems."
(d)
"Cost" means any appropriate operating and maintenance expenses, together with all other costs, including a reasonable return on the licensee's investment, which are reasonably allocable to a transaction.
However, no value shall be included for loss of revenue due to the loss of any wholesale or retail customer as a result of any transaction hereafter described.
(2)
(a)
The licensee will interconnect and coordinate reserves by means of the sale and exchange of emergency and scheduled maintenance bulk power with any neighboring entity(ies), when there are net benefits to each party, on terms that will provide for all of the licensee's properly assignable costs as may be determined by the Federal Energy Regulatory Commission and consistent with such cost assignment will allow the other party the fullest possible benefits of such coordination.
(b)
Emergency service and/or scheduled maintenance service to be provided by each party will be furnished to the fullest extent available from the supplying party and desired by the party in need. The licensee and each party will provide to the other emergency service and/or scheduled maintenance service if and when available from its own generation and, in accordance with recognized industry practice, from generation of other to the extent it can do so without impairing service to its customers, including other electric systems to whom it has firm commitments.
(c)
Each party to a reserve coordination arrangement will establish its own reserve criteria, but in no event shall the minimum installed reserve on each system be less than 15%, calculated as a percentage of estimated peak load responsibility. Either party, if it has, or has firmly planned, installed reserves in excess of the amount called for by its own reserve criterion, will offer any such excess as may in fact be available at the time for which it is sought and for such period as the selling party shall determine for purchase in accordance with reasonable industry practice by the other party to meet such other party's own reserve requirements. The parties will provide such amounts of spinning reserve as may be adequate to avoid the imposition of unreasonable demands on the other part(ies) in meeting the normal contingencies of operating its (their) system(s). However, in no circumstances shall such spinning reserve requirement exceed the installed reserve requirement.
C-2
(d)
Interconnections will not be limited to low voltages when higher voltages are available from the licensee's installed facilities in the area where interconnection is desired and when the proposed arrangement is found to be technically and economically feasible.
(e)
Interconnection and reserve coordination agreements will not embody provisions which impose limitations upon the use or resale of power and energy sold or exchanged pursuant to the agreement. Further, such arrangements will not prohibit the participants from entering into other interconnection and coordination arrangements, but may include appropriate provisions to assure that (i) the licensee receives adequate notice of such additional interconnection or coordination, (ii) the parties will jointly consider and agree upon such measures, if any, as are reasonably necessary to protect the reliability of the interconnected systems and to prevent undue burdens from being imposed on any system, and (iii) the licensee will be fully compensated for its costs. Reasonable industry practice as developed in the area from time to time will satisfy this provision.
(3)
The licensee currently has on file, and may hereafter file, with the Federal Energy Regulatory Commission contracts with neighboring entity(ies) providing for the sale and exchange of short-term power and energy, limited term power and energy, economy energy, non-displacement energy, and emergency capacity and energy. The Licensee will enter into contracts providing for the same or for like transactions with any neighboring entity on terms which enable the licensee to recover the full costs allocable to such transaction.
(4)
The licensee currently sells capacity and energy in bulk on a full requirements basis to several entities engaging in the distribution of electric power at retail. In addition, the licensee supplies electricity directly to ultimate users in a number of municipalities. Should any such entity(ies) or municipality(ies) desire to become a neighboring entity as defined in subparagraph (1)(b) hereof (either alone or through combination with others), the licensee will assist in facilitating the necessary transition through the sale of partial requirements firm power and energy to the extent that, except for such transition, the licensee would otherwise be supplying firm power and energy. The provision of such firm partial requirements service shall be under such rates, terms and conditions as shall be found by the Federal Energy Regulatory Commission to provide for the recovery of the licensee's cost. The licensee will sell capacity and energy in bulk on a full requirements basis to any municipality currently served by the licensee when such municipality lawfully engages in the distribution of electric power at retail.
(5)
(a)
The licensee will facilitate the exchange of electric power in bulk in wholesale transactions over its transmission facilities (1) between or C-3
among two or more neighboring entities including distribution systems with which it is interconnected or may be interconnected in the future, and (2) between any such entity(ies) and any other electric system engaging in bulk power supply between whose facilities the licensee's transmission lines and other transmission lines would form a continuous electric path, provided that permission to utilize such other transmission lines has been obtained. Such transaction shall be undertaken provided that the particular transaction reasonably can be accommodated by the licensee's transmission system from a functional and technical standpoint and does not constitute the wheeling of power to a retail customer. Such transmission shall be on terms that fully compensate the licensee for its cost. Any entity(ies) requesting such transmission arrangements shall give reasonable notice of its (their) schedule and requirements.
(b)
The licensee will include in its planning and construction program sufficient transmission capacity as required for the transactions referred to in subparagraph (a) of this paragraph, provided that (1) the neighboring entity(ies) gives the licensee sufficient advance notice as may be necessary reasonably to accommodate its (their) requirements from a functional and technical standpoint and (2) that such entity(ies) fully compensate the licensee for its cost. In carrying out this subparagraph (b), however, the licensee shall not be required to construct or add transmission facilities which (a) will be of no demonstrable present or future benefit to the licensee, or (b) which could be constructed by the requesting entity(ies) without duplicating any portion of the licensee's existing transmission lines, or (c) which would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements.. Where regulatory or environmental approvals are required for the construction or addition of transmission facilities needed for the transactions referred to in subparagraph (a) of this paragraph it shall be the responsibility of the entity(ies) seeking the transaction to participate in obtaining such approvals, including sharing in the cost thereof.
(6)
To increase the possibility of achieving greater reliability and economy of electric generation and transmission facilities, the licensee will discuss load projections and system development plans with any neighboring entity(ies).
(7)
When the licensee's plans for future nuclear generating units (for which application will hereafter be made to the Nuclear Regulatory commission) have reached the stage of serious planning, but before firm decisions have been made as to the size and desired completion date of the proposed nuclear units, the licensee will notify all neighboring entities including distribution systems with peak loads smaller than the licensee's that the licensee plans to construct such C-4
nuclear units. Neither the timing nor the information provided need be such as to jeopardize obtaining the required site at the lowest possible cost.
(8)
The foregoing commitments shall be implemented in a manner consistent with the provisions of the Federal Power Act and all other lawful local, state and Federal regulation and authority. Nothing in these commitments is intended to determine in advance the resolution of issues which are properly raised at the Federal Energy Regulatory Commission concerning such commitments, including allocation of costs or the rates to be charged. The licensee will negotiate (including the execution of a contingent statement of intent) with respect to the foregoing commitments with any neighboring entity including distribution systems where applicable engaging in or proposing to engage in bulk power supply transactions, but the licensee shall not be required to enter into any final arrangement prior to resolution of any substantial questions as to the lawful authority of an entity to engage in the transactions.
In addition, the licensee shall not be obligated to enter into a given bulk power supply transaction if: (1) to do so would violate, or incapacitate it from performing, and existing lawful contracts it has with a third party; (2) there is contemporaneously available to it a competing or alternate arrangement which affords it greater benefits which would be mutually exclusive of such arrangement; (3) to do so would adversely affect its system operations or the reliability of power supply to its customers, or (4) if to do so would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements.
C-5
DUKE ENERGY CAROLINAS. LLC DOCKET NO. 50-370 MCGUIRE NUCLEAR STATION, UNIT 2 RENEWED FACILITY OPERATING LICENSE Renewed License No. NPF-17
- 1.
The U.S. Nuclear Regulatory Commission (Commission), having previously made the findings set forth in License No. NPF-17 issued on March 3, 1983, has now found that:
A.
The application for renewed operating license filed by the Duke Energy Corporation* complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I and all required notifications to other agencies or bodies have been duly made; B.
Actions have been identified and have been or will be taken with respect to (1) managing the effects of aging during the period of extended operation on the functionality of structures and components that have been identified to require review under 10 CFR 54.21 (a)(1), and (2) time-limited aging analyses that have been identified to require review under 10 CFR 54.21 (c), such that there is reasonable assurance that the activities authorized by the renewed operating license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for the McGuire Nuclear Station, Unit 2 (facility or plant), and that any changes made to the plant's current licensing basis in order to comply with 10 CFR 54.29(a) are in accord with the Act and the Commission's regulations; C.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission; D.
There is reasonable assurance: (i) that the activities authorized by this renewed operating license 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; E.
The licensee is technically qualified to engage in the activities authorized by this renewed operating license in accordance with the Commission's regulations set forth in 10 CFR Chapter I; Duke Energy Corporation converted to Duke Power Company LLC on April 3, 2006 and was re-named Duke Energy Carolinas, LLC as of October 1, 2006. Duke Energy Carolinas, LLC is the owner and operator of McGuire Nuclear Station, Unit 2. References to the "licensee" or "Duke" are to Duke Energy Carolinas, LLC.
Renewed License No. NPF-17 Amendment No. 225 F.
The licensee has satisfied the applicable provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements", of the Commission's regulations; G.
The issuance of this renewed operating license will not be inimical to the common defense and security or to the health and safety of the public; H.
After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of this Renewed Facility Operating License No. NPF-17 is in accordance with 10 CFR Part 51, of the Commission's regulations and all applicable requirements have been satisfied; and, I. The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this renewed operating license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40 and 70.
- 2.
Based on the foregoing findings and the Initial Decisions issued by the Atomic Safety and Licensing Board dated April 18, 1979, and May 26, 1981, and the Decision of the Atomic Safety and Licensing Appeal Board dated March 30, 1982, regarding this facility, Renewed Facility Operating License No. NPF-17 is hereby issued to Duke Energy Carolinas, LLC to read as follows:
A.
This renewed operating license applies to the McGuire Nuclear Station, Unit 2, a pressurized water reactor and associated equipment (the facility) owned and operated by Duke Energy Carolinas, LLC. The facility is located on the site in Mecklenburg County, North Carolina, on the shore of Lake Norman approximately 17 miles northwest of Charlotte, North Carolina, and is described in the Updated Final Safety Analysis Report, as supplemented and amended, and in the Environmental Report, as supplemented and amended.
B.
Subject to the conditions and requirements incorporated herein, the Commission hereby licenses Duke Energy Carolinas, LLC:
(1)
Pursuant to Section 103 of the Act and 10 CFR Part 50, to possess, use, and operate the facility at the designated location in Mecklenburg County, North Carolina, in accordance with the procedures and limitations set forth in this renewed operating license; (2)
Pursuant to the Act and 10 CFR Part 70 to receive, possess and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Updated Final Safety Analysis Report, as supplemented and amended; (3)
Pursuant to the Act and 10 CFR Parts 30, 40 and 70 to receive, possess and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; Renewed License No. NPF-17 Amendment No. 225 (4)
Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; (5)
Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to possess, but not separate, such byproducts and special nuclear materials as may be produced by the operation of McGuire Nuclear Station, Units 1 and 2; and, (6)
Pursuant to the Act and 10 CFR Parts 30 and 40, to receive, possess and process for release or transfer such byproduct material as may be produced by the Duke Training and Technology Center.
C.
This renewed operating 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 The licensee is authorized to operate the facility at a reactor core full steady state power level of 3411 megawatts thermal (100%).
(2)
Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 246, are hereby incorporated into this renewed operating license. The licensee shall operate the facility in accordance with the Technical Specifications.
(3)
Updated Final Safety Analysis Report The Updated Final Safety Analysis Report supplement submitted pursuant to 10 CFR 54.21(d), as revised on December 16, 2002, describes certain future activities to be completed before the period of extended operation.
Duke shall complete these activities no later than March 3, 2023, and shall notify the NRC in writing when implementation of these activities is complete and can be verified by NRC inspection.
The Updated Final Safety Analysis Report supplement as revised on December 16, 2002, described above, shall be included in the next scheduled update to the Updated Final Safety Analysis Report required by 10 CFR 50.71(e)(4), following issuance of this renewed operating license.
Until that update is complete, Duke may make changes to the programs described in such supplement without prior Commission approval, provided that Duke evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59, and otherwise complies with the requirements in that section.
Renewed License No. NPF-17 Amendment No. 246 (4)
Fire Protection Program Duke Energy Carolinas, LLC shall implement and maintain in effect all provisions of the approved fire protection program as described in the Updated Final Safety Analysis Report for the facility and as approved in the SER dated March 1978 and Supplements 2, 5, and 6 dated March 1979, April 1981, and February 1983, respectively, and the safety evaluation dated May 15, 1989, subject to the following provisions:
The licensee may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.
(5)
Protection of the Environment Before engaging in additional construction or operational activities which may result in a significant adverse environmental impact that was not evaluated or that is significantly greater than that evaluated in the Final Environmental Statement dated April 1976, the licensee shall provide written notification to the Office of Nuclear Reactor Regulation.
(6)
Additional Conditions The Additional Conditions contained in Appendix B, as revised through Amendment No. 181, are hereby incorporated into this renewed operating license. Duke Energy Carolinas, LLC shall operate the facility in accordance with the Additional Conditions.
(7)
Antitrust Conditions The licensee shall comply with the antitrust conditions delineated in Appendix C of this renewed operating license.
(8)
Mitigation Strategy License Condition Develop and maintain strategies for addressing large fires and explosions and that include the following key areas:
A)
Fire fighting response strategy with the following elements:
- 1.
Pre-defined coordinated fire response strategy and guidance
- 2.
Assessment of mutual aid fire fighting assets
- 3.
Designated staging areas for equipment and materials
- 4.
Command and control
- 5.
Training of response personnel B)
Operations to mitigate fuel damage considering the following:
1..
Protection and use of personnel assets
- 2.
Communications
- 3.
Minimizing fire spread Renewed License No. NPF-17 Amendment No. 244
- 4.
Procedures for implementing integrated fire response strategy
- 5.
Identification of readily-available pre-staged equipment
- 6.
Training on integrated fire response strategy
- 7.
Spent fuel pool mitigation measures C)
Actions to minimize release to include consideration of:
- 1.
Water spray scrubbing
- 2.
Dose to onsite responders D.
Physical Protection Duke Energy Carolinas, LLC shall fully implement and maintain in effect all provisions of the Commission-approved physical security, 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 combined set of plans, which contains safeguards information protected under 10 CFR 73.21, is entitled: "Duke Energy Physical Security Plan" submitted by letter dated September 8, 2004, and supplemented on September 30, 2004, October 15, 2004, October 21, 2004, and October 27, 2004.
Duke Energy Carolinas, LLC shall fully implement and maintain in effect all provisions of the Commission-approved cyber security plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p).
The Duke Energy Carolinas, LLC CSP was approved by License Amendment No. 244.
E.
Deleted by Amendment No. 215.
F.
The licensee shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.
G.
In accordance with the Commission's direction in its Statement of Policy, Licensing and Regulatory Policy and Procedures for Environmental Protection:
Uranium Fuel Cycle Impacts, October 29, 1982, this renewed operating license is subject to the final resolution of the pending litigation involving Table S-3.
See, Natural Resources Defense Council v. NRC, No. 74-1586 (D.C. cir. April 27,1982).
H.
The licensee is authorized to receive from the Oconee Nuclear Station, Units 1, 2, and 3, possess, and store irradiated Oconee fuel assemblies containing special nuclear material, enriched to not more than 3.24% by weight U-235 subject to the following conditions:
- a.
Oconee fuel assemblies may not be placed in the McGuire Nuclear Station, Unit 1 and 2, reactors.
- b.
Irradiated fuel shipped to McGuire Nuclear Station, Units 1 and 2, from Oconee shall have been removed from the Oconee reactor no less than 270 days prior to shipment.
Renewed License No. NPF-17 Amendment No. 244
- c.
No more than 300 Oconee irradiated fuel assemblies shall be received for storage at McGuire Nuclear Station.
- d.
Burnup of Oconee fuel shipped shall be no greater than 36,000 MW days per metric ton.
- e.
Receipt of irradiated Oconee fuel shall be limited by the use of the NFS-4 (NAC-1), NLI-1/2, TN-8, or TN-8L spent fuel casks.
- f.
The spent fuel pool crane travel shall be restricted by administrative controls to the paths required by Selected Licensee Commitment 16.9.20 whenever a spent fuel cask is being handled.
- g. Oconee fuel assemblies may not be transferred from one McGuire spent fuel pool to the other.
- 3.
This renewed operating license is effective as of the date of issuance and shall expire at midnight on March 3, 2043.
FOR THE NUCLEAR REGULATORY COMMISSION J.E. Dyer, Director Office of Nuclear Reactor Regulation
Attachment:
- 1. Appendix A - Technical Specifications
- 2. Appendix B - Additional Conditions
- 3. Appendix C - Antitrust Conditions Date of Issuance: December 5, 2003 Renewed License No. NPF-17
APPENDIX B ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-17 Duke Energy Carolinas, LLC shall comply with the following conditions on the schedules noted below:
Amendment Additional Implementation Number Conditions Date 166 The schedule for the performance of new and Within 90 days of revised surveillance requirements shall be as the date of this follows:
amendment.
For surveillance requirements (SRs) that are new in Amendment No. 166 the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment No. 166. For SRs that existed prior to Amendment No. 166, including SRs with modified acceptance criteria and SRs whose intervals of performance are being extended, the first performance is due at the end of the first surveillance interval that begins on the date the surveillance was last performed prior to implementation of amendment No. 166. For SRs that existed prior to Amendment No. 166, whose intervals of performance are being reduced, the first reduced surveillance interval begins upon completion of the first surveillance performed after implementation of Amendment No. 166.
Renewed License No. NPF-17 Amendment No. 238 B-1
APPENDIX B ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-17 Duke Power Power Company LLC shall comply with the following conditions on the schedules noted below:
Amendment Additional Implementation Number Conditions Date 229 Upon implementation of the Amendment adopting See Condition TSTF-448, Revision 3, the determination of control room envelope (CRE) unfiltered inleakage as required by SR 3.7.9.4, in accordance with TS 5.5.16.c.(i), the assessment of CRE habitability as required by TS 5.5.16.c.(ii), and the measurement of CRE pressure as required by TS 5.5.16.d, shall be considered met.
Following implementation:
(a) The first performance of SR 3.7.9.4 in accordance with TS 5.5.16.c.(i), shall be within the specified Frequency of 6 years, plus the 18 month allowance of SR 3.0.2, as measured from October 2003, the date of the most recent successful tracer gas test, as stated in the February 19, 2004 letter response to Generic Letter 2003-01, or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.
(b) The first performance of the periodic assessment of CRE habitability, TS 5.5.16.c.(ii), shall be within 3 years, plus the 9 month allowance of SR 3.0.2 as measured from October 2003, the date of the most recent successful tracer gas test, as stated in the February 19, 2004 letter response to Generic Letter 2003-01, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.
(c) The first performance of the periodic measurement of CRE pressure, TS 5.5.16.d, shall be within 18 months, plus the 138 days allowed by SR 3.0.2, as measured from January 2007, the date of the most recent successful pressure measurement test, or within 138 days if not performed previously.
Renewed License No. NPF-17 Amendment No. 229 B-2
APPENDIX C ANTITRUST CONDITIONS Pursuant to an Order by the Atomic Safety and Licensing Board, dated April 23, 1975, the Nuclear Regulatory Commission incorporates in Operating License NPF-17 the following antitrust conditions:
- a. The licensee makes the commitments contained herein, recognizing that bulk power supply arrangements between neighboring entities normally tend to serve the public interest. In addition, where there are net benefits to all participants such arrangements also serve the best interests of each of the participants.
Among the benefits of such transactions are increased electric system reliability, a reduction in the cost of electric power, and minimization of the environmental effects of the production and sale of electricity.
Any particular bulk power supply transaction may afford greater benefits to one participant than to another. The benefits realized by a small system may be proportionately greater than those realized by a larger system. The relative benefits to be derived by the parties from a proposed transaction, however, should not be controlling upon a decision with respect to the desirability of participating in the transaction. Accordingly, the licensee will enter into proposed bulk power transactions of the types hereinafter described which, on balance, provide net benefits to the licensee. There are net benefits in a transaction if the licensee recovers the cost of the transaction (as defined in subparagraph (1)(d) hereof) and there is no demonstrable net detriment to the licensee arising from the transaction.
(1)
As used herein:
(a)
"Bulk Power" means electric power and any attendant energy, supplied or made available at transmission or sub-transmission voltage by one electric system to another.
(b)
"Neighboring Entity" means a private or public corporation, a governmental agency or authority, a municipality, a cooperative, or a lawful association of any of the foregoing owning or operating, or proposing to own or operate, facilities for the generation and transmission of electricity which meets each of the following criteria:
(1) its existing or proposed facilities are economically and technically feasible of interconnection with those of the licensee and (2) with the exception of municipalities, cooperatives, governmental agencies or authorities, and associations, it is, or upon commencement of operations will be, a public utility and subject to regulation with respect to rates and service under the laws of North Carolina or South Carolina or under the Federal Power Act; provided, however, that as to associations, each member of such association is either a public utility as discussed in this clause (2) or C-1
a municipality, a cooperative or a governmental agency or authority.
(c)
Where the phrase "neighboring entity" is intended to include entities engaging or proposing to engage only in the distribution of electricity, this is indicated by adding the phrase "including distribution systems."
(d)
"Cost means any appropriate operating and maintenance expenses, together with all other costs, including a reasonable return on the licensee's investment, which are reasonably allocable to a transaction.
However, no value shall be included for loss of revenue due to the loss of any wholesale or retail customer as a result of any transaction hereafter described.
(2)
(a)
The licensee will interconnect and coordinate reserves by means of the sale and exchange of emergency and scheduled maintenance bulk power with any neighboring entity(ies), when there are net benefits to each party, on terms that will provide for all of the licensee's properly assignable costs as may be determined by the Federal Energy Regulatory Commission and consistent with such cost assignment will allow the other party the fullest possible benefits of such coordination.
(b)
Emergency service and/or scheduled maintenance service to be provided by each party will be furnished to the fullest extent available from the supplying party and desired by the party in need. The licensee and each party will provide to the other emergency service and/or scheduled maintenance service if and when available from its own generation and, in accordance with recognized industry practice, from generation of other to the extent it can do so without impairing service to its customers, including other electric systems to whom it has firm commitments.
(c)
Each party to a reserve coordination arrangement will establish its own reserve criteria, but in no event shall the minimum installed reserve on each system be less than 15%, calculated as a percentage of estimated peak load responsibility. Either party, if it has, or has firmly planned, installed reserves in excess of the amount called for by its own reserve criterion, will offer any such excess as may in fact be available at the time for which it is sought and for such period as the selling party shall determine for purchase in accordance with reasonable industry practice by the other party to meet such other party's own reserve requirements. The parties will provide such amounts of spinning reserve as may be adequate to avoid the imposition of unreasonable demands on the other part(ies) in meeting the normal contingencies of operating its (their) system(s). However, in no circumstances shall such spinning reserve requirement exceed the installed reserve requirement.
(d)
Interconnections will not be limited to low voltages when higher voltages are C-2
available from the licensee's installed facilities in the area where interconnection is desired and when the proposed arrangement is found to be technically and economically feasible.
(e)
Interconnection and reserve coordination agreements will not embody provisions which impose limitations upon the use or resale of power and energy sold or exchanged pursuant to the agreement. Further, such arrangements will not prohibit the participants from entering into other interconnection and coordination arrangements, but may include appropriate provisions to assure that (i) the licensee receives adequate notice of such additional interconnection or coordination, (ii) the parties will jointly consider and agree upon such measures, if any, as are reasonably necessary to protect the reliability of the interconnected systems and to prevent undue burdens from being imposed on any system, and (iii) the licensee will be fully compensated for its costs. Reasonable industry practice as developed in the area from time to time will satisfy this provision.
(3)
The licensee currently has on file, and may hereafter file, with the Federal Energy Regulatory Commission contracts with neighboring entity(ies) providing for the sale and exchange of short-term power and energy, limited term power and energy, economy energy, non-displacement energy, and emergency capacity and energy. The Licensee will enter into contracts providing for the same or for like transactions with any neighboring entity on terms which enable the licensee to recover the full costs allocable to such transaction.
(4)
The licensee currently sells capacity and energy in bulk on a full requirements basis to several entities engaging in the distribution of electric power at retail. In addition, the licensee supplies electricity directly to ultimate users in a number of municipalities. Should any such entity(ies) or municipality(ies) desire to become a neighboring entity as defined in subparagraph (1)(b) hereof (either alone or through combination with others), the licensee will assist in facilitating the necessary transition through the sale of partial requirements firm power and energy to the extent that, except for such transition, the licensee would otherwise be supplying firm power and energy. The provision of such firm partial requirements service shall be under such rates, terms and conditions as shall be found by the Federal Energy Regulatory Commission to provide for the recovery of the licensee's cost. The licensee will sell capacity and energy in bulk on a full requirements basis to any municipality currently served by the licensee when such municipality lawfully engages in the distribution of electric power at retail.
(5)
(a)
The licensee will facilitate the exchange of electric power in bulk in wholesale transactions over its transmission facilities (1) between or among two or more neighboring entities including distribution systems with which it is interconnected or may be interconnected in the future, and (2) between any such entity(ies) and any other electric system engaging in bulk power supply between whose facilities the licensee's transmission C-3
lines and other transmission lines would form a continuous electric path, provided that permission to utilize such other transmission lines has been obtained. Such transaction shall be undertaken provided that the particular transaction reasonably can be accommodated by the licensee's transmission system from a functional and technical standpoint and does not constitute the wheeling of power to a retail customer. Such transmission shall be on terms that fully compensate the licensee for its cost. Any entity(ies) requesting such transmission arrangements shall give reasonable notice of its (their) schedule and requirements.
(b)
The licensee will include in its planning and construction program sufficient transmission capacity as required for the transactions referred to in subparagraph (a) of this paragraph, provided that (1) the neighboring entity(ies) gives the licensee sufficient advance notice as may be necessary reasonably to accommodate its (their) requirements from a functional and technical standpoint and (2) that such entity(ies) fully compensate the licensee for its cost. In carrying out this subparagraph (b), however, the licensee shall not be required to construct or add transmission facilities which (a) will be of no demonstrable present or future benefit to the licensee, or (b) which could be constructed by the requesting entity(ies) without duplicating any portion of the licensee's existing transmission lines, or (c) which would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements. Where regulatory or environmental approvals are required for the construction or addition of transmission facilities needed for the transactions referred to in subparagraph (a) of this paragraph it shall be the responsibility of the entity(ies) seeking the transaction to participate in obtaining such approvals, including sharing in the cost thereof.
(6)
To increase the possibility of achieving greater reliability and economy of electric generation and transmission facilities, the licensee will discuss load projections and system development plans with any neighboring entity(ies).
(7)
When the licensee's plans for future nuclear generating units (for which application will hereafter be made to the Nuclear Regulatory commission) have reached the stage of serious planning, but before firm decisions have been made as to the size and desired completion date of the proposed nuclear units, the licensee will notify all neighboring entities including distribution systems with peak loads smaller than the licensee's that the licensee plans to construct such nuclear units. Neither the timing nor the information provided need be such as to jeopardize obtaining the required site at the lowest possible cost.
The foregoing commitments shall be implemented in a manner consistent with the provisions of the Federal Power Act and all other lawful local, state and Federal regulation and authority. Nothing in these commitments is intended to determine in advance the resolution of issues which are properly raised at the Federal Energy Regulatory Commission concerning such commitments, C-4
including allocation of costs or the rates to be charged. The licensee will negotiate (including the execution of a contingent statement of intent) with respect to the foregoing commitments with any neighboring entity including distribution systems where applicable engaging in or proposing to engage in bulk power supply transactions, but the licensee shall not be required to enter into any final arrangement prior to resolution of any substantial questions as to the lawful authority of an entity to engage in the transactions.
In addition, the licensee shall not be obligated to enter into a given bulk power supply transaction if: (1) to do so would violate, or incapacitate it from performing, and existing lawful contracts it has with a third party; (2) there is contemporaneously available to it a competing or alternate arrangement which affords it greater benefits which would be mutually exclusive of such arrangement; (3) to do so would adversely affect its system operations or the reliability of power supply to its customers, or (4) if to do so would jeopardize the licensee's ability to finance or construct on reasonable terms facilities needed to meet its own anticipated system requirements.
C-5
McGuire Nuclear Station Technical Specifications LOEP Page Number Amendment Revision Date i
243/224 7/26/07 ii 237/219 3/1/07 iii 184/166 9/30/98 iv 184/166 9/30/98 1.1-1 184/166 9/30/98 1.1-2 266/246 6/25/12 1.1-3 237/219 3/1/07 1.1-4 194/175 9/18/00 1.1-5 255/235 5/28/10 1.1-6 261/241 3/29/11 1.1-7 194/175 9/18/00 1.2-1 184/166 9/30/98 1.2-2 184/166 9/30/98 1.2-3 184/166 9/30/98 1.3-1 184/166 9/30/98 1.3-2 184/166 9/30/98 1.3-3 184/166 9/30/98 1.3-4 184/166 9/30/98 1.3-5 184/166 9/30/98 1.3-6 184/166 9/30/98 1.3-7 184/166 9/30/98 1.3-8 184/166 9/30/98 1.3-9 184/166 9/30/98 1.3-10 184/166 9/30/98 1.3-11 184/166 9/30/98 1.3-12 184/166 9/30/98 1.3-13 184/166 9/30/98 1.4-1 184/166 9/30/98 1.4-2 184/166 9/30/98 1.4-3 184/166 9/30/98 1.4-4 184/166 9/30/98 2.0-1 219/201 1114/04 McGuire Units 1 and 2 Page I Revision 93
Page Number Amendment Revision Date 3.0-1 3.0-2 3.0-3 3.0-4 3.0-5 3.1.1-1 3.1.2-1 3.1.2-2 3.1.3-1 3.1.3-2 3.1.3-3 3.1.4-1 3.1.4-2 3.1.4-3 3.1.4-4 3.1.5-1 3.1.5-2 3.1.6-1 3.1.6-2 3.1.6-3 3.1.7-1 3.1.7-2 3.1.8-1 3.1.8-2 3.2.1-1 3.2.1-2 3.2.1-3 3.2.1.4 3.2.1-5 3.2.2-1 3.2.2-2 3.2.2-3 3.2.2-4 3.2.3-1 238/220 221/203 238/220 205/186 221/203 261/241 184/166 261/241 184/166 184/166 184/166 184/166 184/166 261/241 261/241 184/166 261/241 184/166 184/166 261/241 184/166 184/166 184/166 261/241 184/166 184/166 261/241 261/241 261/241 184/166 184/166 261/241 261/241 261/241 3/29/07 4/29/04 3/29/07 8/12/02 4/29/04 3/29/11 9/30/98 3/29/11 9/30/98 9/30/98 9/30198 9/30/98 9/30/98 3/29/11 3/29/11 9/30/98 3/29111 9/30/98 9/30/98 3/29111 9/30/98 9/30/98 9/30/98 3/29111 9/30/98 9/30/98 3/29/11 3/29111 3/29/11 9/30/98 9/30/98 3/29/11 3/29/11 3/29/11 McGuire Units I and 2 Page 2 Revision 93
Page Number 3.2.4-1 3.2.4-2 3.2.4-3 3.2.4-4 3.3.1-1 3.3.1-2 3.3.1-3 3.3.1-4 3.3.1-5 3.3.1-6 3.3.1-7 3.3.1-8 3.3.1-9 3.3.1-10 3.3.1-11 3.3.1-12 3.3.1-13 3.3.1-14 3.3.1-15 3.3.1-16 3.3.1-17 3.3.1-18 3.3.1-19 3.3.1-20 3.3.2-1 3.3.2-2 3.3.2-3 3.3.2-4 3.3.2-5 3.3.2-6 3.3.2-7 3.3.2-8 3.3.2-9 3.3.2-10 McGuire Units I and 2 Amendment 184/166 184/166 184/166 261/241 184/166 248/228 248/228 2161197 250/230 248/228 248/228 184/166 261/241 261/241 261/241 261/241 261/241 257/237 257/237 257/237 257/237 219/201 219/201 184/166 184/166 250/230 248/228 248/228 248/228 198/179 198/179 2611241 261/241 265/245 Page 3 Revision Date 9/30/98 9/30/98 9/30/98 3/29/11 9/30/98 3/9/09 3/9/09 7/29/03 3/9/09 3/9/09 3/9/09 9/30/98 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 8/2/10 8/2/10 8/2/10 8/2/10 1/14/04 1/14/04 9/30/98 9/30/98 3/9/09 3/9/09 3/9/09 319/09 4/12/01 4/12/01 3/29/11 3129/11 9/12/11 Revision 93
Page Nwmbes-Amendment Revision Date 3.3.2-11 265/245 9/12/11 3.3.2-12 265/245 9/12/11 3.3.2-13 265/245 9/12/11 3.3.2-14 265/245 9/12/11 3.3.2-15 265/245 9/12/11 3.3.3-1 221/203 4/29/04 3.3.3-2 227/209 4/4/05 3.3.3-3 261/241 3/29/11 3.3.3-4 227/209 414/05 3.3.4-1 221/203 4/29/04 3.3.4-2 261/241 3/29/11 3.3.4-3 184/166 9/30/98 3.3.5-1 184/166 9/30/98 3.3.5-2 261/241 3/29/11 3.3.6-1 Not Used - 243/224 7/26/07 3.4.1-1 219/201 1/14/04 3.4.1-2 219/201 1/14/04 3.4.1-3 261/241 3/29/11 3.4.1-4 219/201 1/14/04 3.4.2-1 184/166 9/30/98 3.4.3-1 214/195 7/3/03 3.4.3-2 261/241 3/29/11 3.4.3-3 214/195 7/3/03 3.4.3-4 214/195 7/3/03 3.4.3-5 214/195 7/3/03 3.4.3-6 214/195 7/3/03 3.4.3-7 214/195 7/3/03 3.4.3-8 214/195 7/3/03 3.4.4-1 261/241 3/29/11 3.4.5-1 216/197 7/29/03 3.4.5-2 216/197 7/29/03 3.4.5-3 261/241 3/29/11 3.4.6-1 216/197 7/29/03 3.4.6-2 261/241 3/29/11 McGuire Units I and 2 Page 4 Revision 93
Page Nu,,,nber Amendment Revision Date 3.4.7-1 3.4.7-2 3.4.7-3 3.4.8-1 3.4.8-2 3.4.9-1 3.4.9-2 3.4.10-1 3.4.10-2 3.4-11-1 3.4.11-2 3.4-11-3 3.4.11-4 3.4.12-1 3.4.12-2 3.4.12-3 3.4.12-4 3.4.12-5 3.4.12-6 3.4.13-1 3.4.13-2 3.4.14-1 3.4.14-2 3.4.14-3 3.4.14-4 3.4.15-1 3.4.15-2 3.4.15-3 3.4.15-4 3.4.16-1 3.4.16-2 3.4.16-3 3.4.16-4 3.4.17-1 2161197 216/197 261/241 216/197 261/241 184/166 261/241 184/166 184/166 221/203 184/166 184/166 261/241 184/166 221/203 214/195 214/195 261/241 261/241 237/219 261/241 184/166 184/166 261/241 261/241 235/217 235/217 235/217 261/241 266/246 266/246 261/241 184/166 261/241 7/29/03 7/29/03 3/29/11 7/29/03 3/29/11 9/30/98 3/29/11 9/30/98 9/30/98 4/29/04 9/30/98 9/30/98 3/29/11 9/30/98 4/29/04 7/3/03 7/3/03 3/29/11 3/29/11 3/1/07 3/29/11 9/30/98 9/30/98 3/29/11 3/29111 9/30/06 9/30/06 9/30/06 3/29/11 6/25/12 6/25/12 3/29/11 9/30/98 3/29/11 II McGuire Units I and 2 Page 5 Revision 93
Page Num;er Amendment
.Revision Date 3.4.18-1 237/219 3/1/07 3.4.18-2 237/219 3/1/07 3.5.1-1 218/200 12/23/03 3.5.1-2 261/241 3/29/11 3.5.2-1 184/166 9/30/98 3.5.2-2 261/241 3/29/11 3.5.2-3 261/241 3/29/11 3.5.3-1 221/203 4/29/04 3.5.3-2 184/166 9/30/98 3.5.4-1 184/166 9/30/98 3.5.4-2 9/12/11 9/12/11 3.5.5-1 184/166 9/30/98 3.5.5-2 261/241 3/29/11 3.6.1-1 207/188 9/4/02 3.6.1-2 207/188 9/4/02 3.6.2-1 184/166 9/30/98 3.6.2-2 184/166 9/30/98 3.6.2-3 184/166 9/30/98 3.6.2-4 184/166 9/30/98 3.6.2-5 261/241 3/29/11 3.6.3-1 243/224 7/26/07 3.6.3-2 184/166 9/30/98 3.6.3-3 184/166 9/30/98 3.6.3-4 184/166 9/30/98 3.6.3-5 261/241 3/29/11 3.6.3-6 261/241 3/29/11 3.6.3-7 207/188 9/4/02 3.6.4-1 261/241 3/29/11 3.6.5-1 184/166 9/30/98 3.6.5-2 261/241 3/29/11 3.6.6-1 9/12/11 9/12/11 3.6.6-2 9/12/11 9/12/11 3.6.7-1 Not Used - 227/209 4/4/05 3.6.8-1 221/203 4/29/04 McGuire Units 1 and 2 Page 6 Revision 93
Page Numbe!
3.6.8-2 3.6.9-1 3.6.9-2 3.6.10-1 3.6.10-2 3.6.11-1 3.6.11-2 3.6.12-1 3.6.12-2 3.6.12-3 3.6.13-1 3.6.13-2 3.6.13-3 3.6.14-1 3.6.14-2 3.6.14-3 3.6.15-1 3.6.15-2 3.6.16-1 3.6.16-2 3.7.1-1 3.7.1-2 3.7.1-3 3.7.2-1 3.7.2-2 3.7.3-1 3.7.3-2 3.7.4-1 3.7.4-2 3.7.5-1 3.7.5-2 3.7.5-3 3.7.5-4 3.7.6-1 Amendment 261/241 184/166 261/241 184/166 261/241 261/241 261/241 261/241 261/241 261/241 256/236 261/241 261/241 228/210 261/241 261/241 184/166 261/241 261/241 261/241 184/166 184/166 184/166 184/166 184/166 184/166 184/166 221/203 261/241 221/203 184/166 261/241 261/241 184/166 Page 7 3/29/11 9/30/98 3/29/11 9/30/98 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 3129/11 6/28/10 3/29111 3129/11 4/5/05 3/29/11 3/29/11 9/30/98 3/29/11 3/29/11 3/29/11 9/30/98 9/30/98 9/30198 9/30/98 9/30/98 9/30/98 9/30/98 4/29/04 3129/11 4/29/04 9/30/98 3/29/11 3/29/11 9/30/98 Revision Date McGuire Units 1 and 2 Revision 93
Page Number Amendment Revision Date 3.7.6-2 3.7.7-1 3.7.7-2 3.7.8-1 3.7.8-2 3.7.9-1 3.7.9-2 3.7.9-3 3.7.10-1 3.7.10-2 3.7.11-1 3.7.11-2 3.7.12-1 3.7.12-2 3.7.13-1 3.7.14-1 3.7.15-1 3.7.15-2 3.7.15-3 3.7.15-4 3.7.15-5 3.7.15-6 3.7.15-7 3.7.15-8 3.7.15-9 3.7.15-10 3.7.15-11 3.7.15-12 3.7.15-13 3.7.15-14 3.7.15-15 3.7.15-16 3.7.15-17 3.7.15-18 261/241 184/166 261/241 261/241 261/241 249/229 249/229 261/241 184/166 261/241 229/211 261/241 261/241 261/241 261/241 261/241 225/207 225/207 225/207 225/207 225/207 225/207 2251207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 3/29/11 9/30/98 3/29/11 3/29/11 3/29/11 1/30/09 1/30109 3/29111 9/30/98 3/29/11 6/2/05 3/29/11 3/29/11 3/29/11 3/29111 3/29/11 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05
.3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 McGuire Units I and 2 Page 8 Revision 93
Page Number Amendment Revision Date 3.7.15-19 3.7.15-20 3.7.15-21 3.7.15-22 3.7.15-23 3.7.15-24 3.7.15-25 3.7.15-26 3.7.15-27 3.7.15-28 3.7.15-29 3.7.15-30 3.7.15-31 3.7.15-32 3.7.16-1 3.8.1-1, 3.8.1-2 3.8.1-3 3.8.1-4 3.8.1-5 3.8.1-6 3.8.1-7 3.8.1-8 3.8.1-9 3.8.1-10 3.8.1-11 3.8.1-12 3.8.1-13 3.8.1-14 3.8.1-15 3.8.2-1 3.8.2-2 3.8.2-3 3.8.3-1 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 225/207 2251207 225/207 261/241 2211203 184/166 241/-
184/166 261/241 261/241 261/241 261/241 261/241 261/241 261/241 261/241 261/241 261/241 261/241 184/166 216/197 184/166 184/166 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/17/05 3/29/11 4/29/04 9/30/98 618/07 9/30/98 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 9/30/98 7/29/03 9/30/98 9/30/98 McGuire Units 1 and 2 Page 9 Revision 93
Page Number Amendment Revision Date 3.8.3-2 3.8.3-3 3.8.4-1 3.8.4-2 3.8.4-3 3.8.4-4 3.8.5-1 3.8.5-2 3.8.6-1 3.8.6-2 3.8.6-3 3.8.6-4 3.8.7-1 3.8.8-1 3.8.8-2 3.8.9-1 3.8.9-2 3.8.10-1 3.8.10-2 3.9.1-1 3.9.2-1 3.9.3-1 3.9.3-2 3.9.4-1 3.9.4-2 3.9.5-1 3.9.5-2 3.9.6-1 3.9.6-2 3.9.7-1 4.0.1 4.0.2 5.1-1 5.2-1 184/166 261/241 184/166 261/241 261/241 260/240 184/166 216/197 184/166 261/241 261/241 184/166 261/241 184/166 261/241 184/166 261/241 216/197 261/241 261/241 261/241 216/197 261/241 236/218 261/241 216/197 261/241 216/197 2611241 2611241 225/207 225/207 213/194 239/221 9/30/98 3/29/11 9/30/98 3/29/11 3/29/11 12/20/10 9/30/98 7/29/03 9/30/98 3129/11 3/29/11 9/30/98 3/29/11 9/30198 3129/11 9/30/98 3/29111 7/29/03 3/29/11 3/29/11 3/29/11 7/29/03.
3/29/11 12/22/06 3/29/11 7/29/03 3/29/11 7/29/03 3/29/11 3/29/11 3/17/05 3/17/05 6/6/03 04/12/07 McGuire Units 1 and 2 Page 10 Revision 93
Page Number Amendment Revision Date 5.2-2 5.3-1 5.4-1 5.5-1 5.5-2 5.5-3 5.5-4 5.5-5 5.5-6 5.5-7 5.5-8 5.5-9 5.5-10 5.5-11 5.5-12 5.5-13 5.5-14 5.5-15 5.5-16 5.6-1 5.6-2 5.6-3 5.6-4 5.6-5 5.7-1 5.7-2 253/233 213/194 184/166 244/193 212/193 184/166 184/166 223/205 252/232 237/219 237/219 237/219 237/219 237/219 237/219 237/219 249/229 261/241 261/241 226/208 226/208 226/208 230/212 237/219 213/194 184/166 9/21/09 6/6/03 9/30/98 2/13/08 5/8/03 9/30/98 9/30/98 8/5/04 8/17/09 3/1/07 3/1/07 3/1/07 3/1/07 3/1/07 3/1/07 3/1/07 1/30/09 3/29/11 3/29/11 3/1/07 3/1/07 3/1/07 8/23/05 3/1/07 6/6/03 9/30/98 McGuire Units 1 and 2 Page I11 Revision 93
Definitions 1.1 1.1 Definitions (continued)
CHANNEL CHECK CHANNEL OPERATIONAL TEST (COT)
CORE ALTERATION CORE OPERATING LIMITS REPORT (COLR)
DOSE EQUIVALENT 1-131 DOSE EQUIVALENT XE-1 33 A CHANNEL CH.ECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.
A COT shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify the OPERABILITY of required alarm, interlock, and trip functions. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints so that the setpoints are within the required range and accuracy.
CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel.
Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.
The COLR is the unit specific document that provides cycle specific parameter limits for the current reload cycle. These cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Unit operation within these limits is addressed in individual Specifications.
DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes 1-131, 1-132, 1-133, 1-134, and 1-135 actually present.
The determination of DOSE EQUIVALENT 1-131 shall be performed using Committed Dose Equivalent (CDE) or Committed Effective Dose Equivalent (CEDE) dose conversion factors from Table 2.1 of the Environmental Protection Agency (EPA) Federal Guidance Report No. 11.
DOSE EQUIVALENT XE-133 shall be that concentration of Xe-1 33 (microcuries per gram) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-85, Kr-87, Kr-88, Xe-131m, Xe-133m, Xe-133, Xe-135m, Xe-135, and Xe-138 actually present. If a specific noble gas nuclide is not detected, it should be assumed to be present at the minimum detectable activity. The determination of DOSE EQUIVALENT XE-133 shall be performed using effective dose conversion factors for air submersion listed in Table 111.1 of EPA Federal Guidance Report No. 12, 1993, "External Exposure to Radionuclides in Air, Water, and Soil.
(continued)
McGuire Units 1 and 2 1.1-2 Amendment Nos. 266/246
RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 APPLICABILITY:
RCS DOSE EQUIVALENT 1-131 and DOSE EQUIVALENT XE-1 33 specific activity shall be within limits.
MODES 1,2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
DOSE EQUIVALENT
--..--------.---- Note --.....-----------
1-131 not within limit.
LCO 3.0.4.c is applicable.
A.1 Verify DOSE Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> EQUIVALENT 1-131
<6OpCi/gm.
AND A.2 Restore DOSE 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> EQUIVALENT 1-131 to within limit.
B.
DOSE EQUIVALENT Note -.-.----
XE-1 33 not within limit.
LCO 3.0.4.c is applicable.
B.1 Restore DOSE 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> EQUIVALENT XE-1 33 to within limit.
(continued)
I McGuire Units 1 and 2 3.4.16-1 Amendment Nos. 266/246
RCS Specific Activity 3.4.16 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.
Required Action and CA 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 B AND not met.
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 /> OR DOSE EQUIVALENT 1-131 >60pCi/gm.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 NOTE Only required to be performed in MODES 1, 2, and 3 with In accordance RCS average temperature > 5000F.
with the Surveillance Frequency Control Verify reactor coolant DOSE EQUIVALENT XE-133 Program specific activity < 280 pCi/gm.
SR 3.4.16.2 Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity < 1.0 pCi/gm.
In accordance with the Surveillance Frequency Control Program AND Between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after a THERMAL POWER change of> 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period McGuire Units I and 2 3.4.16-2 Amendment Nos. 266/246
McGuire Nuclear Station Technical Specification Bases LOES TS Bases are revised by section Page Number Revision Revision Date ii iii B 2.1.1 B 2.1.2 B 3.0 B 3.1.1 B 3.1.2 B 3.1.3 B 3.1.4 B 3.1.5 B 3.1.6 B 3.1.7 B 3.1.8 B 3.2.1 B 3.2.2 B 3.2.3 B 3.2.4 B 3.3.1 B 3.3.2 (Unit 1)
B 3.3.2 (Unit 2)
B 3.3.3 (Unit 1)
B 3.3.3 (Unit 2)
B 3.3.4 B 3.3.5 B 3.3.6 B 3.4.1 B 3.4.2 B 3.4.3 BASES (Revised per section)
Revision 87 Revision 87 Revision 87 Revision 51 Revision 109 Revision 81 Revision 115 Revision 115 Revision 10 Revision 115 Revision 115 Revision 115 Revision 58 Revision 115 Revision 115 Revision 115 Revision 115 Revision 115 Revision 119 Revision 119 Revision 119 Revision 117 Revision 115 Revision 115 Revision 115 Not Used - Revision 87 Revision 115 Revision 0 Revision 115 8/15/07 8/15/07 8/15/07 01/14/04 9/20/10 3/29/07 3/29/11 3/29/11 9/22/00 3/29/11 3/29/11 3/29/11 06/23/04 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 11/9/11 11/9/11 11/9/11 9/12/11 3/29/11 3/29/11 3/29/11 6/29/06 3/29/11 9/30/98 3/29/11 McGuire Units 1 and 2 Page I Revision 112
Page Number Amendment Revision Date B 3.4.4 B 3.4.5 B 3.4.6 B 3.4.7 B 3.4.8 B 3.4.9 B 3.4.10 B 3.4.11 B 3.4.12 B 3.4.13 B 3.4.14 B 3.4.15 B 3.4.16 B 3.4.17 B 3.4.18 B 3.5.1 B 3.5.2 B 3.5.3 B 3.5.4 (Unit 1)
B 3.5.4 (Unit 2)
B 3.5.5 B 3.6.1 B 3.6.2 B 3.6.3 B 3.6.4 B 3.6.5 B 3.6.6 (Unit 1)
B 3.6.6 (Unit 2)
B 3.6.7 B 3.6.8 B 3.6.9 B 3.6.10 B 3.6.11 (Unit 1)
B 3.6.11 (Unit 2)
Revision 115 Revision 115 Revision 115 Revision 115 Revision 115 Revision 115 Revision 102 Revision 115 Revision 115 Revision 115 Revision 115 Revision 115 Revision 121 Revision 115 Revision 86 Revision 115 Revision 116 Revision 57 Revision 117 Revision 115 Revision 115 Revision 53 Revision 115 Revision 115 Revision 115 Revision 115 Revision 117 Revision 115 Not Used - Revision 63 Revision 115 Revision 115 Revision 120 Revision 117 Revision 115 3/29/11 3(29/11 3/29/11 3/29/11 3/29/11 3/29/11 8/17/09 3/29/11 3/29/11 3/29/11 3/29/11 3/29/11 8/5/09 3/29/11 6/25/07 3/29/11 8/18/11 4/29/04 9/12/11 3/29/11 3/29/11 2/17/04 3/29/11 3/29/11 3/29/11 3/29/11 9/12/11 3/29/11 4/4/05 3/29/11 3/29/11 4/26/12 9/12/11 3/29/11 McGuire Units I and 2 Page 2 Revision 112
Page Number Amendment Revision Date B 3.6.12 Revision 115 3/29/11 B 3.6.13 Revision 115 3/29/11 B 3.6.14 Revision 115 3/29/11 B 3.6.15 Revision 115 3/29/11 B 3.6.16 Revision 115 3/29/11 B 3.7.1 Revision 102 8/17/09 B 3.7.2 Revision 105 2/22/10 B 3.7.3 Revision 102 8/17/09 B 3.7.4 Revision 115 3/29/11 B 3.7.5 Revision 115 3/29/11 B 3.7.6 Revision 115 3/29/11 B 3.7.7 Revision 115 3129/11 B 3.7.8 Revision 115 3/29/11 B 3.7.9 Revision 120 4/26/12 B 3.7.10 Revision 115 3/29/11 B 3.7.11 Revision 115 3/29/11 B 3.7.12 Revision 115 3/29/11 B 3.7.13 Revision 115 3/29/11 B 3.7.14 Revision 115 3/29/11 B 3.7.15 Revision 66 6/30/05 B 3.7.16 Revision 115 3/29/11 B 3.8.1 Revision 115 3/29/11 B 3.8.2 Revision 92 1/28/08 B 3.8.3 Revision 115 3/29/11 B 3.8.4 Revision 115 3/29/11 B 3.8.5 Revision 41 7/29/03 B 3.8.6 Revision 115 3/29/11 B 3.8.7 Revision 115 3/29/11 B 3.8.8 Revision 115 3/29/11 B 3.8.9 Revision 115 3/29/11 B 3.8.10 Revision 115 3/29/11 B 3.9.1 Revision 115 3/29/11 B 3.9.2 Revision 115 3/29/11 B 3.9.3 Revision 115 3/29/11 McGuire Units 1 and 2 Page 3 Revision 112
Page Number Amendment Revision Date B 3.9.4 Revision 115 3/29/11 B 3.9.5 Revision 115 3/29/11 B 3.9.6 Revision 115 3/29/11 B 3.9.7 Revision 115 3/29/11 McGuire Units I and 2 Page 4 Revision 112
RCS Specific Activity B 3.4.16 B 3.4 REACTOR COOLANT SYSTEM (RCS)
B 3.4.16 RCS Specific Activity BASES BACKGROUND The maximum dose that an individual at the exclusion area boundary can receive for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> following an accident, or at the low population zone outer boundary for the radiological release duration, is specified in 10 CFR 100.11 (Ref. 4) or 10 CFR 50.67 (Ref.1). Doses to control room operators must be limited per GDC 19. The limits on specific activity ensure that the offsite and control room doses are appropriately limited during analyzed transients and accidents.
The RCS specific activity LCO limits the allowable concentration level of radionuclides in the reactor coolant. The LCO limits are established to minimize the dose consequences in the event of a steam line break (SLB) or steam generator tube rupture (SGTR) accident.
The LCO contains specific activity limits for both DOSE EQUIVALENT 1-131 and DOSE EQUIVALENT XE-133. The allowable levels are intended to ensure that offsite and control room doses meet the appropriate acceptance criteria.
APPLICABLE SAFETY ANALYSES The LCO limits on the specific activity of the reactor coolant ensure that the resulting offsite and control room doses meet the appropriate acceptance criteria following a SLB or SGTR accident. The safety analyses (Refs. 2 and 3) assume the specific activity of the reactor coolant is at the LCO limits, and an existing reactor coolant total steam generator (SG) tube leakage rate of 389 gpd exists. The safety analyses assume the specific activity of the secondary coolant is at its limit of 0.1 pCi/gm DOSE EQUIVALENT 1-131 from LCO 3.7.16, "Secondary Specific Activity."
The analysis for the SLB and SGTR accidents establish the acceptance limits for RCS specific activity. Reference to these analyses is used to assess changes to the unit that could affect RCS specific activity, as they relate to the acceptance limits.
McGuire Units 1 and 2 B 3.4.16-1 Revision No. 121
RCS Specific Activity B 3.4.16 BASES APPLICABLE SAFETY ANALYSES (continued)
The safety analyses consider two cases of reactor coolant iodine specific activity. One case assumes specific activity at 1.0 pCi/gm DOSE EQUIVALENT 1-131 with a concurrent large iodine spike that increases the rate of release of iodine from the fuel rods containing cladding defects to the primary coolant immediately after a SLB (by a factor of 500), or SGTR (by a factor of 335),
respectively. The second case assumes the initial reactor coolant iodine activity at 60 pCi/gm DOSE EQUIVALENT 1-131 due to an iodine spike caused by a reactor or an RCS transient prior to the accident. In both cases, the noble gas specific activity Is assumed to be 280 pCi/gm DOSE EQUIVALENT XE-133.
The SGTR analysis also assumes a loss of offsite power at the same time as the reactor trip. The SGTR causes a reduction in reactor coolant inventory.
The loss of offsite power causes the steam dump valves to close to protect the condenser. The rise in pressure in the ruptured SG discharges radioactively contaminated steam to the atmosphere through the SG power operated relief valves and the main steam safety valves. The unaffected SGs remove core decay heat by venting steam to the atmosphere until the cooldown ends and the Residual Heat Removal (RHR) system is placed in service.
The SLB radiological analysis assumes that offsite power is lost at the same time as the pipe break occurs outside containment. The affected SG blows down completely and steam is vented directly to the atmosphere. The unaffected SGs remove core decay heat by venting steam to the atmosphere until the cooldown ends and the RHR system is placed in service.
Operation with iodine specific activity levels greater than the LCO limit is permissible for 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, if the activity levels do not exceed 60.0 pCi/gm.
The limits on RCS specific activity are also used for establishing standardization in radiation shielding and plant personnel radiation protection practices.
RCS specific activity satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii).
McGuire Units 1 and 2 B 3.4.16-2 Revision No. 121
RCS Specific Activity B 3.4.16 BASES LCO The iodine specific activity in the reactor coolant is limited to 1.0 pCi/gm DOSE EQUIVALENT 1-131, and the noble gas specific activity in the reactor coolant is limited to 280 pCi/gm DOSE EQUIVALENT XE-133. The limits on specific activity ensure that offsite and control room doses will meet the appropriate acceptance criteria.
The SLB and SGTR accident analyses (Refs. 2 and 3) show that the calculated doses are within acceptable limits. Violation of the, LCO may result in reactor coolant radioactivity levels that could, in the event of a SLB or SGTR, lead to doses that exceed the acceptance criteria.
APPLICABILITY In MODES 1, 2, 3, and 4, operation within the LCO limits for DOSE EQUIVALENT 1-131 and DOSE EQUIVALENT XE-133 is necessary to limit the potential consequences of a SLB or SGTR to within the acceptance criteria.
In MODES 5 and 6, the steam generators are not being used for decay heat removal, the RCS and steam generators are depressurized, and primary to secondary leakage is minimal.
Therefore, the monitoring of RCS specific activity is not required.
ACTIONS A. 1 and A.2 With the DOSE EQUIVALENT 1-131 greater than the LCO limit, samples at intervals of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> must be taken to demonstrate that the specific activity is < 60.0 pCi/gm. The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is required to obtain and analyze a sample. Sampling is continued every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> to provide a trend.
The DOSE EQUIVALENT 1-131 must be restored to within limit within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />. The Completion Time of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> is acceptable since it is expected that, if there were an iodine spike, the normal coolant iodine concentration would be restored within this time period. Also, there is a low probability of a SLB or SGTR occurring during this time period.
A Note permits the use of the provisions of LCO 3.0.4.c. This allowance permits entry into the applicable MODE(S), relying on Required Actions A. 1 and A.2 while the DOSE EQUIVALENT 1-131 LCO limit is not met.
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RCS Specific Activity B 3.4.16 BASES ACTIONS (continued)
This allowance is acceptable due to the significant conservatism incorporated into the specific activity limit, the low probability of an event which is limiting due to exceeding this limit, and the ability to restore transient-specific activity excursions while the plant remains at, or proceeds to, power operation.
B.1 With the DOSE EQUIVALENT XE-133 greater than the LCO limit, DOSE EQUIVALENT XE-1 33 must be restored to within limit within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />. The allowed Completion Time of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> is acceptable since it is expected that, if there was a noble gas spike, the normal coolant noble gas concentration would be restored within this time period. Also, there is a low probability of a SLB or SGTR occurring during this time period.
A Note permits the use of the provisions of LCO 3.0.4.c. This allowance permits entry into the applicable MODE(S), relying on Required Action B.1 while the DOSE EQUIVALENT XE-1 33 LCO limit is not met. This allowance is acceptable due to the significant conservatism incorporated into the specific activity limit, the low probability of an event which is limiting due to exceeding this limit, and the ability to restore transient-specific activity excursions while the plant remains at, or proceeds to, power operation.
C.1 and C.2 If the Required Action and associated Completion Time of Condition A or B is not met, or if the DOSE EQUIVALENT 1-131 is
> 60 pCi/gm, the reactor must be brought to MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.4.16.1 REQUIREMENTS SR 3.4.16.1 requires performing a gamma isotopic analysis as a measure of the noble gas specific activity'of the reactor coolant.
This measurement is the sum of the degassed gamma activities and the gaseous gamma activities in the sample taken. This Surveillance provides an indication of anylincrease in the noble gas specific activity.
McGuire Units 1 and 2 B 3.4.16-4 Revision No. 121
RCS Specific Activity B 3.4.16 BASES SURVEILLANCE REQUIREMENTS (continued)
- Trending the results of this Surveillance allows proper remedial action to be taken before reaching the LCO limit under normal operating conditions.
The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.
If a specific noble gas nuclide listed in the definition of DOSE EQUIVALENT XE-133 is not detected, it should be assumed to be present at the minimum detectable activity.
A Note modifies the SR to allow entry into and operation in MODE 4 and MODE 3 with RCS average temperature < 500OF prior to performing the SR. This allows the establishment of the necessary plant conditions to produce sufficient sample flow.
SR 3.4.16.2 This Surveillance is performed to ensure iodine specific activity remains within the LCO limit during normal operation and following fast power changes when iodine spiking is more apt to occur. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. The Frequency, between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after a power change >15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period, is established because the iodine levels peak during this time following iodine spike initiation; samples at other times would provide inaccurate results.
REFERENCES
- 1.
- 2.
UFSAR, Section 15.1.5.
- 3.
UFSAR, Section 15.6.3.
- 4.
McGuire Units 1 and 2 B 3.4.16-5 Revision No. 121