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Resolution No. 91131 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 RESOLUTION NO. 9113 A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF VERNON APPROVING AND RATIFYING THE EXECUTION OF AN AMENDMENT TO THE TRANSMISSION CONTROL AGREEMENT AMONG THE CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION, THE PARTICIPATING TRANSMISSION OWNERS AND PROSPECTIVE NEW PARTICIPATING TRANSMISSION OWNERS WHEREAS, by Resolution No. 8271 adopted on August 27, 2003, the City of Vernon approved a Transmission Control Agreement ("TCA") among the California Independent System Operator Corporation ("ISO") and the Participating Transmission Owners and Prospective New Participating Transmission Owners; and WHEREAS, the ISO wants to amend the TCA to adopt an ISO Transmission Maintenance Standard and to update individual Participating Transmission Owner's entitlements and encumbrances; and WHEREAS, Light & Power staff reviewed the proposed changes which do not affect the City's Appendix to the TCA and recommended that the amended TCA be approved and executed; and WHEREAS, the ISO required that the amended TCA be executed in counterparts and delivered to it prior to August 11, 2006, for filing with the Federal Energy Regulatory Commission for approval; and WHEREAS, in order to meet the urgent need to meet the filing deadline, the Mayor executed the amended TCA on August 8, 2006, subject to ratification by the _City Council; and WHEREAS, the City Council desires to approve and ratify the actions of the Mayor in executing the amended TCA. NOW, THEREFORE, BE IT RESOLVED BY THE CITY COUNCIL OF THE CITY OF VERNON AS FOLLOWS: 1 2 3 4 b 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 SECTION 1: The City Council of the City of Vernon hereby finds and determines that the recitals contained hereinabove are true and correct. SECTION 2: The City Council of the City of Vernon hereby approves and ratifies the execution of the amended Transmission Control Agreement by the Mayor on August 8, 2006, a copy of which is attached hereto as Exhibit A and incorporated by reference. SECTION 3: The Acting City Clerk of the City of Vernon shall certify to the passage of this resolution, and thereupon and thereafter the same shall be in full force and effect. APPROVED AND ADOPTED this 16tn day of August, 2006. ATTEST: BRUCE V. MA ENHORST, JR. Acting City Clerk EONIS C. MAL URG, ayor - 2 - 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 STATE OF CALIFORNIA ) ) ss COUNTY OF LOS ANGELES ) I, BRUCE V. MALKENHORST, JR., Acting City Clerk of the City of Vernon, do hereby certify that the foregoing Resolution, being Resolution No. 9113, was duly adopted by the City Council of the City of Vernon at a regular meeting of the City Council duly held on Wednesday, August 16, 2006, and thereafter was duly signed by the Mayor of the City of Vernon. 11�7 (SEAL) BRUCE VvMALKENHORST, City Clerk - 3 - EXHIBIT A CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 Second Revised Sheet No. I SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 1$' Revised Sheet No. I TABLE OF CONTENTS Se 1. DEFINITIONS............................................................................................ ...............3 2. PARTICIPATION IN THIS AGREEMENT..............................................................._....3 3. EFFECTIVE DATE, TERM AND WITHDRAWAL........................................................9 4. TRANSFER OF OPERATIONAL CONTROL............................................................15 5. INDEPENDENT SYSTEM OPERATOR....................................................................27 6. PARTICIPATING TRANSMISSION OWNERS..........................................................32 7. SYSTEM OPERATION AND MAINTENANCE..........................................................36 8. CRITICAL PROTECTIVE SYSTEMS THAT SUPPORT ISO CONTROLLED GRID OPERATIONS .................. ........37 ....................................... 9. SYSTEM EMERGENCIES........................................................................................39 10. ISO CONTROLLED GRID ACCESS AND INTERCONNECTION ...........................40 11. EXPANSION OF TRANSMISSION FACILITIES.....................................................44 12. USE AND ADMINISTRATION OF THE ISO CONTROLLED GRID ........................44 13. EXISTING AGREEMENTS......................................................................................45 14. MAINTENANCE STANDARDS...................................................................... .....46 15. DISPUTE RESOLUTION.........................................................................................48 16. BILLING AND PAYMENT....................................................................... ..............48 17. RECORDS AND INFORMATION SHARING...........................................................49 18. GRANTING RIGHTS -OF -ACCESS TO FACILITIES...............................................52 19. [INTENTIONALLY LEFT BLANK] ............................................................................53 20. TRAINING............................................................................................................54 21.OTHER SUPPORT SYSTEMS REQUIREMENTS..................................................54 22. LIABILITY...........................................................................................................55 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 of 4 . j . CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 Second Revised Sheet No. ii SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 18' Revised Sheet No. li 23. UNCONTROLLABLE FORCES...............................................................................57 24. ASSIGNMENTS AND CONVEYANCES.................................................................58 25. ISO ENFORCEMENT .............................................. ....58 26. MISCELLANEOUS........................................................................................... .....58 27. SIGNATURE PAGE CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION...........................................................................64 28. SIGNATURE PAGE PACIFIC GAS AND ELECTRIC COMPANY ...........................65 29. SIGNATURE PAGE SAN DIEGO GAS & ELECTRIC COMPANY ..........................66 30. SIGNATURE PAGE SOUTHERN CALIFORNIA EDISON COMPANY ...................67 31. SIGNATURE PAGE CITY OF VERNON.................................................................68 32. SIGNATURE PAGE CITY OF ANAHEIM................................................................69 33. SIGNATURE PAGE CITY OF AZUSA.....................................................................70 34. SIGNATURE PAGE CITY OF BANNING................................................................71 35. SIGNATURE PAGE CITY OF RIVERSIDE.............................................................72 36. SIGNATURE PAGE OF TRANS -ELECT NTD PATH 15, LLC..............................72A 37. SIGNATURE PAGE OF WESTERN AREA POWER ADMINISTRATION, SIERRA NEVADA REGION............................................72B 38. SIGNATURE PAGE OF CITY OF PASADENA................................. 72C 39. SIGNATURE PAGE OF TRANS BAY CABLE LLC.............................................. 72D APPENDICES A — FACILITIES AND ENTITLEMENTS PG&E Appendix A and Supplement Edison Appendix A and Supplement SDG&E Appendix A and Supplement Vernon Appendix A Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Second Revised Sheet No. III SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 14 Revised Sheet No, III Anaheim Appendix A Azusa Appendix A Banning Appendix A Riverside Appendix A Trans -Elect NTD Path 15, LLC Appendix A Western Area Power Administration, Sierra Nevada Region Appendix A Pasadena Appendix A Trans Bay Cable LLC Appendix A APPENDICES B - ENCUMBRANCES PG&E Appendix B Edison Appendix B SDG&E Appendix B Vernon Appendix B Anaheim Appendix B Azusa Appendix B Riverside Appendix B Pasadena Appendix B APPENDIX C - ISO MAINTENANCE STANDARDS APPENDIX D - MASTER DEFINITIONS SUPPLEMENT APPENDICES E - NUCLEAR PROTOCOLS Diablo Canyon Appendix E SONGS Appendix E APPENDIX F - NOTICES Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 11 ° ' r CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 23A 4.4.4 Trans Bay Cable 4.4.4.1 In addition to the foregoing, the ISO, Trans Bay Cable LLC ("Trans Bay Cable"), and the Participating TOs acknowledge and agree that, following the ISO's approval of Trans Bay Cable's application for Participating TO status and upon the effective date of Trans Bay Cable's TO Tariff as approved by FERC, Trans Bay Cable shall be entitled and obligated to recover the just and reasonable costs of developing, financing, constructing, operating and maintaining transmission assets and associated facilities forming part of the network in which it has Entitlements through Trans Bay Cable's Transmission Revenue Requirement as established from time to time by FERC, including the specific rate principles approved by FERC in Docket No. ER05-985, to the extent that the transmission assets and associated facilities used to provide the Entitlements, as well as the Entitlements themselves, are placed under ISO Operational Control. 4.4.4.2 In reliance on the continued availability of a FERC-approved Transmission Revenue Requirement, as set forth above, Trans Bay Cable will not withdraw from this Agreement except in connection with the transfer, sale or disposition of any of its Entitlements in compliance with Sections 3.3, 4.4, and any other applicable provision of this Agreement. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 23B 4.4.4.3 If Trans Bay Cable should seek to transfer, sell or dispose of its Entitlements or any part thereof, then in addition to any and all other obligations imposed on such a transfer, sale or disposition by this Agreement, any applicable provisions of the ISO Tariff, and FERC rules and regulations, Trans Bay Cable shall require as a condition of such transfer, sale or disposition that the transferee of any of its Entitlement(s): (a) assume in writing Trans Bay Cable's rights and obligations under this Agreement, including without limitation all of the obligations imposed by this Section 4.4.4, e.g., the obligation to recover the just and reasonable costs of developing, financing, constructing, operating and maintaining transmission assets and associated facilities forming part of the network in which it has Entitlements, as set forth in Section 4.4.4.1, exclusively through a FERC-approved Transmission Revenue Requirement; (b) become a Participating TO in the ISO; and (c) assume the obligation to bind each and every one of its transferees, successors and assigns to all of the obligations assumed by Trans Bay Cable under this Agreement. For the avoidance of doubt, the transfer of any of Trans Bay Cable Entitlements cannot take place unless and until the holder of any such Entitlements has, in conjunction with the transfer, become a Participating TO in the ISO. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 t, i CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 23C 4.4.4.4 For the avoidance of doubt, the Parties hereby also confirm that the Operating Memorandum dated May 16, 2005, between Trans Bay Cable, the City of Pittsburg, California, and Pittsburg Power Company and filed by Trans Bay Cable in Docket No. ER05-985, including the option agreement contained therein, does not address or pertain to any transfer, disposition, sale or purchase of any of Trans Bay Cable's Entitlements. 4.4.4.5 Nothing in this Section 4.4.4 shall be interpreted as affecting the right of any party to seek to increase or decrease, at the FERC or appeals therefrom, the established or proposed Transmission Revenue Requirement of Trans Bay Cable or any subsequent holder of any of the Entitlements. 4.4.4.6 Notwithstanding the foregoing subsections of Section 4.4.4, this Section 4.4.4 shall become null and void in the event of and upon the first to occur of: (a) Trans Bay Cable receives for three (3) consecutive months either an underpayment, pursuant to Section 11.18.3 of the ISO Tariff, or a pro rats reduction in payments under Section 11.16.1 of the ISO Tariff, with each such underpayment or pro rata reduction equal to or greater than twenty percent (20%) of the monthly amount due and owing to Trans Say Cable from the ISO, or (b) Trans Bay Cable receives either an Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 b , ' 0 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 23D underpayment, pursuant to Section 11.18.3 of the ISO Tariff or a pro rota reduction in payments under Section 11.16.1 of the ISO Tariff which, when calculated on a cumulative annual basis, is equal to or greater than five percent (5%) of the total amount due and owing to Trans Bay Cable from the ISO for the twelve (12) month period ending prior to the month or months in which such underpayment or pro rats reduction occurs, provided such an underpayment or pro rata reduction does not result from: (i) Access Charge sales fluctuations that impact the monthly Access Charge revenue disbursement to Trans Bay Cable, but which are subject to annual TRBAA true -ups to be made by the Participating TO pursuant to Section 6.1 of Schedule 3 of Appendix F of the ISO Tariff; (ii) Trans Bay Cable's action or failure to act; (iii) an error that has been corrected by the ISO; or (iv) a billing or payment dispute between Trans Bay Cable and the ISO. 4.4.4.7 Should this Section 4.4.4 become null and void under Section 4.4.4.6, then Trans Bay Cable, the ISO and the other Participating TOs shall remain bound by all of the remaining provisions of this Agreement. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO, 7 Second Revised Sheet No. 39 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENTSuperseding Sub.1" Rev. Sheet No. 39 9. SYSTEM EMERGENCIES 9.1. ISO Management of Emergencies. The ISO shall manage a System Emergency pursuant to the provisions of Section 2.3.2 of the ISO Tariff. The ISO may carry out unannounced tests of System Emergency procedures pursuant to the ISO Tariff. 9.2. Management of Emergencies by Participating TOs. 9.2.1 ISO Orders. in the event of a System Emergency, the Participating TOs shall comply with all directions from the ISO regarding the management and alleviation of the System Emergency unless such compliance would impair the health or safety of personnel or the general public. 9.2.2 Communication. During a System Emergency, the ISO and Participating TOs shall communicate through their respective control centers, in Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 46 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 46 14. MAINTENANCE STANDARDS 14.1. ISO Determination of Standards. The ISO has adopted and shall maintain, in consultation with the Participating TOs through the Transmission Maintenance Coordination Committee, and in accordance with the requirements of this Agreement, the standards for the maintenance, inspection, repair, and replacement of transmission facilities under its Operational Control in accordance with Appendix C. These standards, as set forth in Appendix C, are and shall be performance -based or prescriptive or both, and provide for high quality, safe, and reliable service and shall take into account costs, local geography and weather, the Applicable Reliability Criteria, national electric industry practice, sound engineering judgment and experience. 14.2. Availability. 14.2.1 Availability Measure. The ISO performance -based standards shall be based on the availability measures described in Appendix C of this Agreement. 14.2.2 Excluded Events. Scheduled Approved Maintenance Outages and certain Forced Outages will be excluded pursuant to Appendix C of this Agreement from the calculation of the availability measure. 14.2.3 Availability Measure Target. The ISO and each Participating TO shall jointly develop for the Participating TOs an availability measure target, which may be defined by a range. The target will be based on prior Participating TO performance and developed in accordance with Appendix C of this Agreement. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 47 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 47 14.2.4 Calculation of Availability Measure. The availability measure shall be calculated annually by the Participating TO and reported to the ISOfor evaluation of the Participating TO's compliance with the availability measure target. This calculation will be determined in accordance with Appendix C of this Agreement. 14.2.5 Compliance with Availability Measure Target. The ISO and the Participating TO may track the availability measure on a more frequent basis (e.g., quarterly, monthly), but the annual calculation shall be the sole basis for determining the Participating TOs compliance with its availability measure target. 14.2.6 Public Record. The Participating TOs annual availability measure calculation with its summary data shall be made available to the public. 14.3. Revisions. The ISO and Participating TOs shall periodically review Appendix C, through the Transmission Maintenance Coordination Committee process, and in accordance with the provisions of Appendix C and this Agreement shall modify Appendix C as necessary. 14.4. Incentives and Penalties. The ISO may, subject to regulatory approval, and as set forth in Appendix C, develop programs which reward or impose sanctions on Participating TOs by reference to their availability measure and the extent to which the availability performance imposes demonstrable costs or results in demonstrable benefits to Market Participants. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 . 1. CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 48 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 48 15. DISPUTE RESOLUTION In the event any dispute regarding the terms and conditions of this Agreement is not settled, the Parties shall follow the ISO ADR Procedure set forth in Section 13 of the ISO Tariff. The specific references in this Agreement to alternative dispute resolution procedures shall not be interpreted to limit the Parties' rights and obligations to invoke dispute resolution procedures pursuant to this Section 15. 16. BILLING AND PAYMENT 16.1 Application of ISO Tariff The ISO and Participating TOs shall comply with the billing and payment provisions set forth in Section 11 of the ISO Tariff. 16.2 Refund Obligation Each Participating TO, whether or not it is subject to the rate jurisdiction of the FERC under Section 205 and Section 206 of the Federal Power Act, shall make all refunds, adjustments to its Transmission Revenue Requirement, and adjustments to its TO Tariff and do all other things required of a Participating TO to implement any FERC order related to the ISO Tariff, including any FERC order that requires the ISO to make payment adjustments or pay refunds to, or receive prior period overpayments from, any Participating TO. All such refunds and adjustments shall be made, and all other actions taken, in accordance with the ISO Tariff, unless the applicable FERC order requires otherwise. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 49 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 49 17. RECORDS AND INFORMATION SHARING 17.1. Records Relevant to Operation of ISO Controlled Grid. The ISO shall keep such records as may be necessary for the efficient operation of the ISO Controlled Grid and shall make appropriate records available to a Participating TO, upon request. The ISO shall maintain for not less than five (5) years: (1) a record of its operating orders and (2) a record of the contents of, and changes to, the ISO Register. 17.2. Participating TO Records and Information Sharing. 17.2.1 Existing Maintenance Standards. Each Participating TO shall provide to the ISO, as set forth in Appendix C hereto, (1) the Participating TO's standards for inspection, maintenance, repair, and replacement of its facilities under the ISO's Operational Control; and (2) information, notices, or reports regarding the Participating TO's compliance with the inspection, maintenance, repair, and replacement standards set forth in Appendix C hereto. 17.2.2 Other Records. Each Participating TO shall provide to the ISO and maintain current data, records, and drawings describing the physical and electrical Properties of the facilities under the ISO's Operational Control, which records shall be shared with the ISO under reasonable guidelines and procedures to be specified by the ISO. 17.2.3 Required Reports. Pursuant to this Agreement and the provisions of the ISO Tariff, each Participating TO shall provide to the ISO timely information, notices, or reports regarding matters of mutual concern, including: Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 EfEeclive: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 50 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 50 i. System Emergencies, Forced Outages and other incidents affecting the ISO Controlled Grid; Maintenance Outage requests, including yearly forecasts required by Section 2.3.3.5 of the ISO Tariff; and System Planning Studies, including studies prepared in connection with Interconnections or any transmission facility enhancement or expansion 17.2.4 Other Reports. The ISO may, in accordance with the provisions of this Agreement and Appendices hereto, upon reasonable notice to the Participating TO, request that the Participating TO provide the ISO with such information or reports as are necessary for the operation of the ISO Controlled Grid. The Participating TO shall make all such information or reports available to the ISO in the manner and time prescribed by this Agreement or Appendices hereto or, if no specific requirements are so prescribed, within a reasonable time and in a form to be specified by the ISO. 17.2.5 Other Market Participant Information. At the request of the ISO, a Participating TO shall provide the ISO with non -confidential information obtained by the Participating TO from other Market Participants pursuant to contracts between the Participating TO and such other Market Participants. Such requests shall be limited to information that is reasonably necessary for the operation of the ISO Controlled Grid. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Reviser) Sheet No. 52 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 52 notify all other Parties if it becomes aware that a significant incident affecting the ISO Controlled Grid has occurred. Subsequent to notification, each Party shall snake available to the ISO all relevant data related to the occurrence of the significant incident. Such data shall be sufficient to accommodate any reporting or analysis necessary for the Parties to meet their obligations under this Agreement. 17.5. Review of Information and Record -Related Policies. The ISO shall periodically review the requirements of this Section 17 and shall, consistent with reliability and regulatory needs, other provisions of this Agreement, and Appendices hereto, seek to standardize reasonable record keeping, reporting, and information sharing requirements. 18. GRANTING RIGHTS -OF -ACCESS TO FACILITIES 18.1. Equipment Installation. In order to meet its obligations under this Agreement, a Party that owns, rents, or leases equipment (the equipment owner) may require installation of such equipment on property owned by another Party (the property owner), provided that the property is being used for an electric utility purpose and that the property owner shall not be required to do so if it would thereby be prevented from performing its own obligations or exercising its rights under this Agreement. 18.1.1 Free Access. The property owner shall grant to the equipment owner free of charge reasonable installation rights and rights of access to accommodate equipment inspection, repair, upgrading, or removal for the purposes of this Agreement, subject to the property owner's reasonable safety, operational, and future expansion needs. Issued by: Charles F. Robinson, Vice President and General Counsel Issuer) on: August 11, 2006 Effective: October 10, 2006 . ror CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Fourth Revised Shut No. 64 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 3"' Revised Sheet No. 64 27. SIGNATURE PAGE CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION California Independent System Operator Corporation has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendices A Appendices B Appendix C Appendix D Appendices E Appendix F CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION 151 Blue Ravine Road Folsom, California 95630 by: Jim Detmers Vice President, Operations Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 Fourth Revised Sheet No. 65 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding a Revised Sheet No. 66 28. SIGNATURE PAGE PACIFIC GAS AND ELECTRIC COMPANY Pacific Gas and Electric Company has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (PG&E) Appendix B (PG&E) Appendix C Appendix Appendix E (Diablo Canyon) Appendix F PACIFIC GAS AND ELECTRIC COMPANY 77 Beale Street San Francisco, California 94105 Jeffrey Butler Senior Vice President, Transmission & Distribution Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 .. .' . � 1% CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Third Revised Sheet No. 66 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 2"d Revised Sheet No. 66 29. SIGNATURE PAGE SAN DIEGO GAS & ELECTRIC COMPANY San Diego Gas & Electric Company has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (SDG&E) Appendix B (SDG&E) Appendix C Appendix D Appendix E (SONGS) Appendix F SAN DIEGO GAS & ELECTRIC COMPANY 8330 Century Park Court San Diego, California 92123 by: James Avery Senior Vice President of San Diego Gas & Electric Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 ti. ' w CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 Third Revised Sheet No. 67 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 2nd Revised Sheet No. 67 30. SIGNATURE PAGE SOUTHERN CALIFORNIA EDISON COMPANY Southern California Edison Company has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Edison) Appendix B (Edison) Appendix C Appendix D Appendix E (SONGS) Appendix F SOUTHERN CALIFORNIA EDISON COMPANY 2244 Walnut Grove Avenue Rosemead, California 91770 by: Richard M. Rosenblum Senior Vice President, Transmission & Distribution Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 68 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 68 31. SIGNATURE PAGE CITY OF VERNON CITY OF VERNON has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 8t�' day of August, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Vernon) Appendix B (Vernon) Appendix C Appendix D Appendix E Appendix F CITY OF VERNON By: EONIS C. MA BURG, Mayor ATTEST: BRUCE V. MALKENHORST, JR. Acting City Clerk APPROVED AS TO FORM: , Chief Assistant City Attorney Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 69 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 69 32. SIGNATURE PAGE CITY OF ANAHEIM CITY OF ANAHEIM has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Anaheim) Appendix B (Anaheim) Appendix C Appendix D Appendix F CITY OF ANAHEIM By: Marcie L. Edwards Public Utilities General Manager ATTEST: APPROVED AS TO FORM: Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 70 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 70 33. SIGNATURE PAGE CITY OF AZUSA CITY OF AZUSA has caused this Transmission Gontrol Agreement to be executed by its duty authorized representative on this day of 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Azusa) Appendix B (Azusa) Appendix C Appendix D Appendix F CITY OF AZUSA By: Cristina C. Madrid Mayor Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 71 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 71 34. SIGNATURE PAGE CITY OF BANNING CITY OF BANNING has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Banning) Appendix C Appendix D Appendix F CITY OF BANNING By: John Hunt Mayor ATTEST: APPROVED AS TO FORM: Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 72 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 72 35. SIGNATURE PAGE CITY OF RIVERSIDE CITY OF RIVERSIDE has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Riverside) Appendix B (Riverside) Appendix C Appendix D Appendix F CITY OF RIVERSIDE 3900 Main Street, 4'" Floor Riverside, California 92522 By: George A. Caravalho, City Manager ATTEST: City Clerk APPROVED AS TO FORM: Supervising Deputy City Attorney Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 ,x, 7 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 Third Revised Sheet No. 72A SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 2"d Revised Sheet No. 72A 36. SIGNATURE PAGE TRANS -ELECT NTD PATH 15, LLC TRANS -ELECT NTD PATH 15, LLC has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Trans -Elect) Appendix C Appendix D Appendix F Trans -Elect NTD Path 15, LLC 1850 Centennial Park Drive Suite 480 Reston, VA 20191 By: Robert D. Dickerson Executive Vice President Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 Second Revised Sheet No. 72B SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 1" Revised Sheet No. 72B 37. SIGNATURE PAGE WESTERN AREA POWER ADMINISTRATION, SIERRA NEVADA REGION WESTERN AREA POWER ADMINISTRATION, SIERRA NEVADA REGION has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Western) Appendix C Appendix D Appendix F Western Area Power Administration, Sierra Nevada Region Sierra Nevada Region 114 Parkshore Drive Folsom, CA 95630-4710 By: James D. Keselburg Regional Manager Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 Z` to CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 72C SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 72C 37. SIGNATURE PAGE CITY OF PASADNA CITY OF PASADENA has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Pasadena) Appendix B (Pasadena) Appendix C Appendix D Appendix F City of Pasadena Water and Power Department 150 S. Los Robles, Suite 200 Pasadena, CA 91101 By: Cynthia J. Kurtz City Manager Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 72D 39. SIGNATURE PAGE TRANS BAY CABLE LLC TRANS BAY CABLE LLC has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of Agreement: , 2006 and thereby incorporates the following Appendices in this Appendix A (Trans Bay Cable LLC) Appendix C Appendix D Appendix F i ns Ba Cable LLC Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: Upon notice after October 10, 2006 'r' 4 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 75 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Orig. Sheet No. 75 APPENDIX A2 List of Entitlements Being Placed Under ISO Operational Control (includes only those where PG&E is a service rights -holder) Ref. Entitles Contract / Rate Nature of Termination Comments # Schedule # Contract 1. Pacific Power & Transmission Use Transmission Upon 40 years Light, SCE, Agreement —PP&L Rate beginning approx. SDG&E Schedule with FERC 1968 2. SCE, SDG&E Calif. Companies Pacific Transmission 8/1/2007 Both entitlement Intertie Agreement — and encumbrance. PG&E Rate Schedule FERC No. 38 3. SCE, Montana WSCC Unscheduled Flow Operation of Evergreen, or on No transmission Power, Nevada Mitigation Plan — PG&E control facilities to notice services provided, Power, Sierra Rate Schedule FERC No. mitigate loop flows but classified as Pacific 183 an entitlement since loop flow is reduced or an encumbrance if PG&E is asked to Cut. 4. TANC and other Owners Coordinated Transmission 1/1/2043, or on Both entitlement COTP Operations Agreement — system two years' notice, and encumbrance Participants, and PG&E Rate Schedule coordination, or earlier if other WAPA FERC No. 229 curtailment agreements sharing, rights terminate allocation, scheduling 6. Various — See Western Systems Power Power Sales, Upon WSPP Both entitlement Attachment A Pool Agreement — WSPP transmission expiration and encumbrance. 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Q m 3 -n ® =n 3 3 L•'• �' 33 3 3 m m v as 3 0 y 3 3 z m co 3 m 3 ro cn F'' 0 co 7 ^ ca n ' ° m -0. o n 0 n to aR to34m0 0 cD s 79 O ® ag om co cn co co co cn co co co w w w w cD o'n _ O L 3 -� M 3 M z z � m zz S. o o K O ®$ n m m o m m• m m too o .Ni 2 pN m 3 ' oo v w cn co A A w N _ O 3o rn �z o -n z�n3'� m N ---tpQ ' Ci N owi N W -w+ O Wy N CD N co N oo N pi e mz m z �X as z c� m z -IO c G M m ;u to o m o0 Om'} m 9 'U nn Z :� -i .4 z O A Cn O z O z O r M m m m z 4 n co n 24 CL m K m N <�. 9D. z0o ww CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 103D Appendix A Trans Bay Cable, LLC Transmission Entitlements Trans Bay Cable Project Facilitles Trans Bay Cable L.LC (TBC) will develop, finance and construct a high voltage, direct current transmission line of approximately fifty-five miles in length and associated facilities to establish a direct connection between Pacific Gas and Electric Company's (PG&E's) Pittsburg Substation located at a site adjacent to the City of Pittsburg, California in Contra Costa County to PG&E's Potrero Substation within the City of San Francisco (the Project). The transmission line will consist of an approximately 7,000 ton bundled cable consisting of a transmission cable, a fiber optic communications cable and a metallic return. The underwater portion of the transmission line will be laid by a ship or barge with special equipment in a single trench underneath San Francisco Bay. The remaining length of the transmission line (most likely a few hundred yards at either end of the line) will be buried underground, either through directional drilling or laid in a trench. In addition, the Project will involve the construction of two converter stations near each of the PG&E Substations to convert the alternating current received at the Pittsburg Substation to direct current and then back to alternating current at the Potrero Substation. TBC will provide the funding for (i) the development and construction of the Project, (ii) the acquisition of all needed real property and other interests and (iii) the reimbursement of the on -going operation and maintenance expenses of the Project. In return and pursuant to the Operating Memorandum among TBC, the City of Pittsburg and Pittsburg Power Company which was accepted for filing by the Federal Energy Regulatory Commission (11 2 FERC 161,095, order granting clarification, 114 FERC ¶ 61,031), TBC will be granted 100% of the Entitlements to the transmission capacity created by the Project and all financial benefits associated with the Entitlements. In accordance with the TCA and the TO Tariff, TBC will transfer the Entitlements created by the Project to ISO Operational Control at the time the Project enters service. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: Upon notice after October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 105 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 105 List of Encumbrances on Lines and Facilities, and Entitlements Being Placed Under ISO Operational Control (per TCA Appendix Al & A2) (Includes only those where PG&E is a service provider) Abbreviations Used:CDWR SCE SDG&E SMUD TANC WAPA = California Department of Water Resources = Southern California Edison Company = San Diego Gas & Electric Company = Sacramento Municipal Utility District = Transmission Agency of Northern California = Western Area Power Administration Ref. Entities Contract / Rate Nature of Termination Comments # Schedule # Contract 1. Bay Area Rapid Service Agreement Network 10/1/2016 Transit Nos. 42 and 43 to Integration FERC Electric Tariff, Transmission First Revised Volume Service No. 12 Agreement and Network Operating Agreement - OAT 2. CDWR Comprehensive Interconnection 12/31/2014 Transmission Agreement — PG&E and Transmission Related Losses Rate Schedule FERC No. 77 3. CDWR Etiwanda Power Plant Power exchanges Evergreen, or Generation Exchange on 5 years — PG&E Rate notice Schedule FERC No. 169 4. Dynegy Power Control Area Transmission and Terminated Services Transmission various other 12131/01. Agreement — PG&E services PG&E filing of Rate Schedule FERC FERC No. 224 termination pending submittal. 9 The treatment of current rights, including scheduling priorities, relating to the listed Encumbrances are set forth in the operating instnxtions submitted by the PTO in accordance with the ISO Tariff and the TCA. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 106 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 106 Ref. Entities Contract / Rate Nature of Termination Comments # Schedule # Contract S. DOE PG&E/WAPA/DOE-SF Transmission 3/31/2009 Laboratories, 10/30/98 Settlement Service WAPA Agreement — PG&E Rate Schedule FERC No. 147 6. Midway -Sunset Cogeneration Project Interconnection, 1/1/2017 Co -Generation Special Facilities — transmission PG&E Rate Schedule FERC No. 182 7. Minnesota Service Agreement No. Firm Point to- 10/1/2016 Effective 1011/96 Methane 1, under FERC Electric Point Tariff, First Revised Transmission Volume No. 12 1 Service - OAT 8. Modesto Irrigation Interconnection Interconnection, 4/1/2008 Power sales are District Agreement — PG&E transmission, coordination Rate Schedule FERC power sales sales — voluntary No. 116 s t sales 9. NCPA, CSC, Castle Rock -Lakeville Transmission Evergreen, or 1 CDWR CoTenancy Agreement facilities year notice — PG&E Rate maintenance after 1/1/2015 Schedule FERC No. 139 10. Path 15 Operating Exhibit B-1 to this Implements Upon request Instructions Appendix B to the TCA curtailment by PG&E after Settlement, priorities 1/1/05, subject Revision 1 — consistent with to FERC Various, see various Existing acceptance. FERC Docket No. Transmission ER04-61-000 Contracts. Establishes Path 15 Facilitator role for PG&E. 11. Power Exchange Control Area Transmission and Terminated Transmission Service various other 3/1/2000. Agreement — PG&E services PG&E filing of Rate Schedule FERC FERC No. 186 termination pending submittal 12. Puget Sound Capacity and Energy Power exchanges Terminates on Power & Light Exchange — PG&E 5 years' Rate Schedule FERC advance notice. No. 140 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 107 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 107 Ref. Entities Contract / Rate Nature of Termination Comments # Schedule # Contract 13. San Francisco Interconnection Interconnection, 7/1/2015 Power sales are (City and County Agreement - PG&E transmission and Finn Partial of) Rate Schedule FERC supplemental Requirements No. 114 power sales 14. Santa Clara (City Mokelumne Settlement Transmission, 1/1/2034 of) and Grizzly power sales Development Agreement — PG&E Service Agreement No. 20 under FERC Electric Tariff Sixth Revised Volume No. 5 15. SCE, SDG&E Calif. Companies Transmission 8/1/2007 Both entitlement Pacific Interne service and Agreement — PG&E encumbrance. Rate Schedule FERC No. 38 16. SCE, Montana WSCC Unscheduled Operation of Evergreen, or No transmission. Power Nevada Flow Mitigation Plan — control facilities to on notice services Power, Sierra PG&E Rate Schedule mitigate loop provided, but Pacific FERC No. 221 flows classified as an entitlement since loop flow is reduced or an encumbrance if PG&E isasked to cut. 47. Shelter Cove Interconnection Distribution 6/30/2006 Effective 8115/96 Agreement — PG&E Rate Schedule FERC No. 198 18. Siena Pacific Interconnection Interconnection Evergreen, or 3 Agreement — PG&E and support years notice Rate Schedule FERC services No. 72 19. SMUD Interconnection Interconnection 12/31/2009 Agreement — PG&E and transmission Rate Schedule FERC services No. 136 20. SMUD EHV Transmission Transmission Terminated Agreement — PG&E 1/1/2005 Rate Schedule FERC (appeal No. 37pending) 21. SMUD Camp Far West Transmission No notice of Transmission termination Agreement— PG&E filed with FERC Rate Schedule FERC No. 91 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 108 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 108 Ref. Entities Contract / Rate Nature of Tennination Commenis # Schedule # Contract 22. SMUD Slab Creek Transmission No notice of Transmission termination Agreement — PG&E filed with FERC Rate Schedule FERC No. 88 23. TANC and other Owners Coordinated Transmission 1/1/2043, or on Both entitlement COTP Operations Agreement system two years' notiee, and Participants, and — PG&E Rate coordination, or earlier if encumbrance WAPA Schedule FERC No. curtailment other 229 sharing, rights agreements allocation, terminate scheduling. 24. TANC and other COTP Interconnection Interconnection Upon COTP Rate Schedule — termination of Participants PG&E Rate Schedule COTP FERC No. 144 25. TANC Midway Transmission Transmission, Same as the Service / South of curtailment COTP Interim Tesla Principles — priority mitigation,* Participation PGE& Rate Schedule replacement Agreement, FERC No. 143 power subject to exception 26. Turlock Irrigation Interconnection Interconnection, 4/1/2008, District Agreement — PG&E transmission subject to Rate Schedule FERG exception No. 213 27. Vernon (City of) Transmission Service Transmission 7/31/2007, or Both entitlement Exchange Agreement service by extension to and — PG&E Rate 12/15/2042 encumbrance. Schedule FERC No. PG&E swap of 148 DC Line rights for Vernon's COTP tights 28. WAPA San Luis Unit— Transmission 4/1/2016 Contract No. 2207A — PG&E Rate Schedule FERC No. 227 (superseding Original Tariff Sheet Nos. 104 through 137 of PG&E Rate Schedule FERC No. 79 Includes use of PG&E's DC Intertie or PDCI for prespecified mitigation of curtailments over Path 15. Issued by. Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 109 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 109 Ref.# Entities Contract / Rate Nature of Termination Gorrnments T Schedule # Contract 29. WAPA New Melons — Transmission 6/1/2032 Per WAPA, Contract No. 8-07-20- commercial P0004 — PG&E Rate operation date Schedule FERC No. 60 for New Melones was 6/1/82 Lien MoEtgage The lien of the First and Refunding Mortgage dated December 1, 1920 between PG&E and BNY Western Trust Company, as trustee, as amended and supplemented and in effect of the date hereof (the °PG&E Mortgage'). The transfer of Operation Control to the ISO pursuant to this Agreement shall in no event be deemed to be a lien or charge on the PG&E Property which would be prior to the lien of the PG&E Mortgage; however, no consent of the trustee under the PG&E Mortgage is require to consummate the transfer of Operation Control to the ISO pursuant to this Agreement. Issued by: Charles F. 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INTRODUCTION.............................................................................................. • •.................141 2.1. OBJECTIVE........................................................................................................................142 2.2. AVAILABILITY.....................................................................................................................143 2.3. MAINTENANCE DOCUMENTATION REQUIREMENTS.....................................................146 2.4. AVAILABILITY DATA STANDARDS....................................................................................146 3. FACILITIES COVERED BY THESE ISO TRANSMISSION MAINTENANCE STANDARDS... 146 4. AVAILABILITY MEASURES ........................... .........147 4.1. CALCULATION OF AVAILABILITY MEASURES FOR INDIVIDUAL TRANSMISSION LINE CIRCUITS...................................................................................................................................147 4.1.1 FREQUENCY AND DURATION .................. .................................................................147 4.1.2. CAPPING FORCED OUTAGE"""' DURATIONS..........................................................149 4.1.3. EXCLUDED OUTAGES"ms......................................... 149 4.2. AVAILABILITY MEASURE TARGETS............................................................ ...................149 4.2.1. CALCULATIONS OF ANNUAL AVAILABILITY MEASURES INDICES FOR INDIVIDUAL VOLTAGECLASSES............................................................................. ..........................152 4.2.2. DEVELOPMENT OF LIMITS FOR CONTROL CHARTS 4.2.2.1. CENTER CONTROL LINES(CLs).............................................................................154 4.2.2.2. UCLS, LCLs, UWLS AND LWLs.................................................................................156 4.2.3. EVALUATION OF AVAILABILITY MEASURES PERFORMANCE................................161 TABLE 4.2.1 PERFORMANCE INDICATIONS PROVIDED BY CONTROL CHART TESTS ...... 164 4.3. AVAILABILITY REPORTING...............................................................................................165 5. MAINTENANCE PRACTICES.............................................................................................165 5.1. INTRODUCTION ............................................ .............................................................165 5.2. PREPARATION OF MAINTENANCE PRACTICES.............................................................165 5.2.1. TRANSMISSION LINE CIRCUIT MAINTENANCE........................................................165 5.2.1.1. OVERHEAD TRANSMISSION LINES.......................................................................165 5.2.1.2. UNDERGROUND TRANSMISSION LINES...............................................................166 5.2.2. STATION MAINTENANCE...........................................................166 ................................. 5.2.3. DESCRIPTIONS OF MAINTENANCE PRACTICES ................... ..........167 5.3. REVIEW AND ADOPTION OF MAINTENANCE PRACTICES.............................................167 5.3.1. INITIAL ADOPTION OF MAINTENANCE PRACTICES................................................167 5.3.2. AMENDMENTS TO THE MAINTENANCE PRACTICES ............................. .....168 5.3.2.1. AMENDMENTS PROPOSED BY THE ISO...............................................................168 5.3.2.2. AMENDMENTS PROPOSED BY A PTO...................................................................168 5.3.3. DISPOSITION OF RECOMMENDATIONS...................................................................168 5.3.3.1.......................................................................................................................................... 5.3.3.2.............................................................................................................................................. 5.3.3.3............................................................................................................................. .............. 5.4. QUALIFICATIONS OF PERSONNEL..................................................................................171 6. MAINTENANCE RECORD KEEPING AND REPORTING...................................................171 6.1. PTO MAINTENANCE RECORD KEEPING............................................................................... 6.2. PTO MAINTENANCE REPORTING....................................................................................171 6.3. ISO VISIT TO PTO'S TRANSMISSION FACILITIES ...........................................................IT2 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 1 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO, 7 First Revised Sheet No. 139 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 139 7. ISO AND TRANSMISSION MAINTENANCE COORDINATION COMMITTEE .....................172 8. REVISION OF ISO TRANSMISSION MAINTENANCE STANDARDS AND MAINTENANCE PROCEDURES.................................................................................................................172 8.1. REVISIONS TO ISO TRANSMISSION MAINTENANCE STANDARDS ..................................... 8.2. REVISIONS TO AND DEVIATIONS FROM MAINTENANCE PROCEDURES ........................... 9. INCENTIVES AND PENALTIES.................................................................... ...............173 9.1 DEVELOPMENT OF A FORMAL PROGRAM .................................................. .172 ............... 9.2 ADOPTION OF A FORMAL PROGRAM.................................................................. 173 9.3 IMPOSITION OF PENALTIES 1N THE ABSENCE OF A FORMAL PROGRAM ............... 173 9.4 NO WAIVER................................................................................................ . 173 9.5 LIMITATIONS ON APPLICABILITY TO NEW PTOS................................................... 174 10. COMPLIANCE WITH OTHER REGULATIONS/LAWS........................................................174 10.1 SAFETY...........................................................................................................................175 11. DISPUTE RESOLUTION.....................................................................................................174 1. DEFINITIONS' Availability - A measure of time a Transmission Line Circuit under ISO Operational Control is capable of providing service, whether or not it actually is in service. Availability Measures - Within each Voltage Class in a calendar year: 1) the average Forced Outage(" ` $) frequency for all Transmission Line Circuits, 2) the average accumulated Forced Outage('ms) duration for only those Transmission Line Circuits with Forced Outagest'"'S?, and 3) the proportion of Transmission Line Circuits with no Forced Outages('""S) Availability Measure Tarrtets - The Availability performance goals jointly established by the ISO and a PTO for that PTO's Transmission Facilities. Forced Outage(ms) — An event that occurs when a Transmission Facility is in an Outage(Ims) condition for which there is no Scheduled Outage(" "s) request in effect. ' A term followed by the superscript "(IMS)" denotes a term which has a special, unique definition in this Appendix C. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 140 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 140 ISO Transmission Maintenance Standards - The Maintenance standards set forth in this Appendix C. Maintenance - Maintenance as used herein, unless otherwise noted, encompasses inspection, assessment, maintenance, repair and replacement activities performed with respect to Transmission Facilities. Maintenance Practices - A confidential description of methods used by PTO, and adopted by the ISO, for the Maintenance of that PTO's Transmission Facilities. Maintenance Procedures — Documents developed by the Transmission Maintenance Coordination Committee for use by the ISO and the PTOs to facilitate compliance with the ISO Transmission Maintenance Standards. These documents shall serve as guidelines only. Ou a e(1Ms) - Any interruption of the flow of power in a Transmission Line Circuit between any terminals under ISO Operational Control. PTO - A participating TO as defined in Appendix D of the Transmission Control Agreement. Scheduled Outage(ms) - The removal from service of Transmission Facilities in accordance with the requirements of Section 7.1 of the Transmission Control Agreement and the applicable provisions of the ISO Tariff and ISO Protocols. Station — Type of Transmission Facility used for such purposes as line termination, voltage transformation, voltage conversion, stabilization, or switching. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 141 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 141 Transmission Facilities - All equipment and components transferred by a PTO to the ISO for Operational Control, pursuant to the Transmission Control Agreement, such as overhead and underground transmission lines, Stations, and associated facilities. Transmission Line Circuit - The continuous set of transmission conductors, under the ISO Operational Control, located primarily outside of a Station, and apparatus terminating at interrupting devices, which would be isolated from the transmission system following a fault on such equipment. Transmission Maintenance Coordina ion Committee "TM C" - The committee described in Section 7 of this Appendix C. Voltage Class - The voltage to which operating, performance, and Maintenance characteristics are referenced. Voltage Classes are defined as follows: Voltage Class Range of Nominal Voltage 69 kV < 70 kV 115kV 110-161 kV 230 kV 200 - 230 kV 345 kV 280 - 345 kV 500 kV 500 kV HVDC HVDC Capitalized terms, not expressly defined above, are used consistently with the definitions provided in the Transmission Control Agreement and the ISO Tariff. 2. INTRODUCTION This Appendix C delineates the ISO Transmission Maintenance Standards and has been developed through a lengthy consensus building effort involving initially the ISO Maintenance Standards Task Force, and currently the TMCC. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 142 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No, 142 Flexibility in establishing these ISO Transmission Maintenance Standards is implicit in the goal of optimizing Maintenance across a system characterized by diverse environmental and climatic conditions, terrain, equipment, and design practices. To provide for flexibility while ensuring the reasonableness of each PTO's approach to Maintenance, each PTO will prepare its own Maintenance Practices that shall be consistent with the requirements of these ISO Transmission Maintenance Standards. The effectiveness of each PTO's Maintenance Practices will be gauged through the Availability performance monitoring system. Each PTO's adherence to its Maintenance Practices will be assessed through an ISO review. In developing these ISO Transmission Maintenance Standards, both the ISO Maintenance Standards Task Force and TMCC determined that it is impractical to develop and/or impose on the PTOs a single uniform set of prescriptive practices delineating conditions or time -based schedules for various Maintenance activities that account for the myriad of equipment, operating Conditions, and environmental conditions within the ISO Controlled Grid. For this reason, these ISO Transmission Maintenance Standards provide requirements for the PTOs in preparing their respective Maintenance Practices. 2.1. OBJECTIVE This Appendix C provides for a high quality, safe, and reliable ISO Controlled Grid by meeting the following objectives: • Ensuring that the Availability performance levels inherent to the Transmission Facilities are maintained, • Restoring Availability to the levels inherent to the Transmission Facilities when degradation has occurred, Issued by: Charles E. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 143 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 143 • Economically extending the useful life of the Transmission Facilities while maintaining inherent levels of Availability, and • Achieving the aforementioned objectives at a r-unimum reasonable total cost for Maintenance with the intent of minimizing customer impacts. 2.2. AVAILABILITY ISO Controlled Grid reliability is a function of a complex set of variables, including accessibility of alternative paths to serve Load, Generating Unit availability, Load forecasting and resource planning; speed, sophistication and coordination of protection systems; and the Availability of Transmission Line Circuits owned by the PTOs. Availability Measures have been chosen as the principal determinant of each PTO's Maintenance effectiveness. When using Availability Measures as a general gauge of Maintenance effectiveness, several things must be considered to avoid misinterpreting performance. Availability is a function of several variables, including Transmission Facility Maintenance, initial design, extreme exposure, capital improvements, and improvements in restoration practices. These factors should be taken into account when assessing Availability Measures and Maintenance effectiveness. It is important to consider that Maintenance is one of many variables that impact changes in Availability. For example, certain Forced Outages"" that impact Availability may be due to events that generally cannot be controlled by Maintenance. If Availability Measures are either improving or declining, it is important to investigate the cause(s) and any trends that are causing change before drawing conclusions. If Maintenance is being performed by a PTO consistent with Good Utility Practice, increasing Maintenance activities by a significant order may not result in a corresponding increase in Availability and if Maintenance is not performed consistent Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet NO. 144 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 144 with Good Utility Practice, Availability may decline. Thus, while Maintenance is important to ensure Availability, unless a PTO fails to perform Maintenance on a basis consistent with Good Utility Practice, significant increases in Maintenance activities will generally not lead to substantial improvements in Availability and associated ISO Controlled Grid reliability. A variety of techniques can be used to monitor Maintenance effectiveness. However, techniques that do not account for random variations in processes have severe limitations in that they may yield inconsistent and/or erroneous assessments of Maintenance effectiveness. To account for random/chance variations while enabling monitoring for shifts and trends, control charts have been widely accepted and utilized. Control charts are statistically based graphs which illustrate both an expected range of performance for a particular process based on historical data, and discrete measures of recent performance. The relative positions of these discrete measures of recent performance and their relationship to the expected range of performance are used to gauge Maintenance effectiveness. To enhance the use of Availability Measures as a gauge of Maintenance effectiveness, it is necessary to exclude certain types of Outages(" "s). These excluded Outages('"'S), as set forth in more detail in Section 4.1.3 of this Appendix C, are: • Scheduled Outages(IMS); • Outages('""s) classified as "Not a Forced Outage" in the Maintenance Procedures; • Forced Outages(IMS) caused by events originating outside the PTO's system; or • Forced Outages('Ms) demonstrated to have been caused by earthquakes. Additionally, as described in Section 4.1.2 of this Appendix C, the Forced Outage(IMS) duration used to calculate the Availability control charts has been capped at 72 hours so that excessively long Forced Outages(" "s) do not skew the data as to detract from the meaningfulness and interpretation of the control charts for accumulated Forced Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 I CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 145 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 145 Outage"" duration. This is not to say that an excessively long Forced Outage"" is not a concern. Rather, such Forced Outages'""$) should be investigated to assess the reasons for their extended duration. Establishing Availability Measures requires each PTO to use separate control charts for each Voltage Class. Existing Forced Outage('"9) data contains significant differences in the Availability between Voltage Classes and between PTOs. These differences may be attributable to factors such as the uniqueness of operating environments, Transmission Facility designs, and PTO operating policies. Regardless of the cause of these differences, review of the Forced Outage('""S) data makes it eminently apparent that differences are such that no single set of control chart parameters for a particular Voltage Class could be applied to all PTOs. Three types of control charts are utilized to provide a complete representation of historical Availability Measures, and to provide a benchmark against which future Availability Measures can be gauged. The three types of control charts for each PTO and Voltage Class are: • The annual average Forced Outage(l""s) frequency for all Transmission Line Circuits; • The annual average accumulated Forced Outage("'$) duration for those Transmission Line Circuits which experience Forced Outages('"'$); and • The annual proportion of Transmission Line Circuits that experienced no Forced Outagest'""SI These three control charts assist the ISO and PTOs in assessing the Maintenance effectiveness of each Voltage Class over time. To accommodate this process on a cumulative basis, data is made available to the ISO by each PTO at the beginning of each new calendar year to assess past calendar years. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 146 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 146 2.3. MAINTENANCE DOCUMENTATION REQUIREMENTS Two specific requirements regarding Maintenance documentation are incorporated into these ISO Transmission Maintenance Standards. First, these standards require that each PTO develop and submit a description of its Maintenance Practices to the ISO. Second, these standards require that each PTO retain Maintenance records as set forth in Section 6.1 of this Appendix C and make those records available to the ISO as set forth in the Maintenance Procedures, in order to demonstrate compliance with each element of its Maintenance Practices. 2.4. AVAILABILITY DATA STANDARDS To facilitate processing Forced Outage(lms)data for the Availability Measures, and to enable consistent and equitable interpretation of PTO Maintenance records by the ISO, these standards address the need for data recording and reporting. The TMCC has also developed standardized formats for transmitting Forced Outage('m8) data to the ISO for the Availability Measures. These standard formats are provided in the Maintenance Procedures. To facilitate review of the data by the ISO, the TMCC has developed a standard Availability Measures reporting system detailed in the Maintenance Procedures and in Section 4 of this Appendix C. This system will provide for consistent gathering of information that can be used as the basis for analyzing Availability Measures trends. 3. FACILITIES COVERED BY THESE ISO TRANSMISSION MAINTENANCE STANDARDS The ISO Transmission Maintenance Standards set forth in this Appendix C shall apply to all Transmission Facilities. Each PTO shall maintain its Transmission Facilities in Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 147 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 147 accordance with its Maintenance Practices as adopted by the ISO in accordance with these ISO Transmission Maintenance Standards. 4. AVAILABILITY MEASURES 4.1. CALCULATION OF AVAILABILITY MEASURES FOR INDIVIDUAL TRANSMISSION LINE CIRCUITS 4.1.1 FREQUENCY AND DURATION The calculation of the Availability Measures will be performed utilizing Forced Outage('"'s) data through December 31 st of each calendar year. Separate Forced Outage") frequency and accumulated Forced Outage('""S) duration Availability Measures shall be calculated as follows for each Transmission Line Circuit under ISO Operational Control within each Voltage Class. The calculations shall be performed annually for each of the Transmission Line Circuits utilizing all appropriate Forced Outage'Ms) data for the calendar year in question. Forced Outache('m$) Freauengy: The Forced Outage('" frequency (fk) of the i"' Transmission Line Circuit shall equal the total number of Forced Outages"s)that occurred on the i h Transmission Line Circuit during the calendar year "k". See Notes 1 and 2. NOTES: 1. Multiple momentary Forced Outages(") on the same Transmission Line Circuit in the span of a single minute shall be treated as a single Forced. Outage("" ) with a duration of one minute. When the operation of a Transmission Line Circuit is restored following a Forced OutageP""s) and the Transmission Line Circuit remains operational for a period exceeding one minute, i.e., 61 seconds or more, followed by another Forced Outs&e('""s), then these should be counted as two Forced Outages°""sr. Multiple Forced Outages( s) occurring as a result of a single event should be handled as multiple Forced Outages('" only if subsequent operation of the Transmission Line Circuit between events exceeds one minute. Otherwise they shall be considered one continuous Forced Outage('""s) 2. If a Transmission Line Circuit, e.g., a new Transmission Line Circuit, Is only in service for a portion of a calendar year, the Forced Outage('""s) fnequency and accumulated duration data shall be treated as Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 148 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 148 if the Transmission Line Circuit had been in service for the entire calendar year, i.e., the Forced Outage"" data for that Transmission Line Circuit shall be handled the same as those for any other Transmission Line Circuit. Accumulated Forced Outa,g,e!f) Duration: The accumulated Forced Outage('MS) duration in minutes shall be calculated as follows for each of the Transmission Line Circuits having a Forced Outage('""') frequency (fk ) greater than zero for the calendar year W: .fik d ik -" Z O ijk j=1 where dik = accumulated duration of Forced Outages('""S) (total number of Forced Outage(IMS) minutes) for the 1wTransmission Line Circuit having a Forced Outage(lms)frequency (fik) greater than zero for the calendar year 'V. fk = Forced Outage(1°"S)frequency as defined above for calendar year W. oik = duration in minutes of the " w Forced Outage('"'') which occurred during the "e" calendar year for the "i"'" Transmission Line Circuit. See Notes 1 and 2. The durations of extended Forced Outages("'$) shall be capped as described in Section 4.1.2 of this Appendix C for the purposes of calculating the Availability Measures. In addition, certain types of Outages{" "s) shall be excluded from the calculations of the Availability Measures as described in Section 4.1.3 of this Appendix C. If a PTO makes changes to its Transmission Line Circuit identification, configuration, or Forced outage") data reporting schemes, the PTO shall notify the ISO at the time of the change. In its annual report to the ISO, the PTO shall provide recommendations regarding if and how the Availability Measures and Availability Measure Targets should be modified to ensure that they (1) remain consistent with the modified Transmission Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 . ' ,r: f CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No_ 149 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 149 Line Circuit identification or Forced Outage('"'S)data reporting scheme, and (2) provide an appropriate gauge of Availability. 4.1.2. CAPPING FORCED OUTAGE'") DURATIONS The duration of each Forced Outage("'which exceeds 72 hours (4320 minutes) shall be capped at 4320 minutes for the purpose of calculating the accumulated Forced Outage(") duration. 4.1.3. EXCLUDED OUTAGES cu"s> The following types of Outages('"'S) shall be excluded from the calculation of the Availability Measures and the Availability Measure Targets: • Scheduled Outages('"°s) • Outages('""S) classified as "Not a Forced Outage" in the Maintenance Procedures. • Forced Outages('""S) which: (1) were caused by events outside the PTO's system including Outages""'s) which originate in other TO systems, other electric utility systems, or customer equipment, or (2) are Outages('"'S)which can be demonstrated to have been caused by earthquakes. 4.2. AVAILABILITY MEASURE TARGETS The Availability Measure Targets described herein shall be phased in over a period of five calendar years beginning on the date a Transmission Owner becomes a PTO in accordance with the provisions of the Transmission Control Agreement. The adequacy of each PTO's Availability Measures shall be monitored through the use of charts. These charts, called control charts as shown in Figure 4.2.1, are defined by a horizontal axis with a scale of calendar years and a vertical axis with a scale describing the expected range of magnitudes of the index in question. Annual performance Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 I CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 160 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 160 indices shall be plotted on these charts and a series of tests may then be performed to assess the stability of annual performance, shifts in performance and longer -term performance trends. Control charts for each of the following indices shall be developed and utilized to monitor Availability Measures for each Voltage Class within each PTO's system: c� m Annual performance Index c /77-- 0 0 V V C----------------------------------- 98 99 00 01 02 03 04 05 06 07 Year Figure 4.2.1 Sample Control Chart UCL UWL CL LWL LCL • Index 1: Annual Average Forced Outagel'maa Frequency for All Transmission Line Circuits. • Index 2: Annual Average Accumulated Forced Outage('ms) Duration for those Transmission Line Circuits with Forced Outages'""S). • Index 3: Annual Proportion of Transmission Line Circuits with No Forced Outages'"'>. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 151 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 161 The control charts incorporate a center control line (CL), upper and lower control limits (UCL and LCL, respectively), and upper and lower warning limits (UWL and LWL, respectively). The CL represents the average annual historical performance for a period prior to the current calendar year. The UCL and LCL define a range of expected performance extending above and below the CL. For the annual proportion of Transmission Line Circuits with no Forced Qutagesl'"s), the limits are based on standard control chart techniques for binomial proportion data. For the other two indices, bootstrap resampling techniques are used to determine empirical UCL and LCL at 99.75% and 0.25% percentile values, respectively, for means from the historical data. The bootstrap procedure is described in Section 4.2.2 of this Appendix C. Similarly, the UWL and LWL define a range of performance intending to cover the percentiles from 2.5% to 97.5%. The bootstrap algorithm is also used to determine these values. Thus, the UCL and LCL will contain about 99.5% of resampling means from the Voltage Class of interest. UWL and LWL will contain about 95% of the resampling means. These limits coincide with the usual choices for control charts when the means are approximately normal. Bootstrap estimation procedures are used here since the sampling means do not follow the normal distribution model. The bootstrap estimation procedures ensure consistent control chart limits by using a starting base number ("seed") for its random number generator. Accuracy or reduced variances in the control chart limits are attained by using the average control chart limits generated from applying ten repetitions or cycles of the bootstrap sampling method. Collectively, the CL, UCL, LCL, UWL and LWL provide reference values for use in evaluating performance as described in Section 4.2.3 of this Appendix C. For the special case where there is a Voltage Class with only one Transmission Line Circuit, individual and moving range control charts should be used for Index 1 and 2. The method used herein for calculating Index 3 is not applicable for those Voltage Classes containing less than six Transmission Line Circuits. The Maintenance Procedures will be used by the PTCs to calculate Index 1, 2, or 3 where the methods provided herein do not apply. More information on the individual and moving range Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 162 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 162 control charts can be found in the user manuals of the statistical software recommended by the TMCC and approved by the ISO Governing Board for use in creating the control charts. 4.2.1. CALCULATIONS OF ANNUAL AVAILA131LITY MEASURES INDICES FOR INDIVIDUAL VOLTAGE CLASSES Separate annual Availability Measures indices shall be calculated for each Voltage Class and each PTO as described below by utilizing the calculations discussed in Section 4.1 of this Appendix C. Annual Averacie Forced Outage(lms) Frequency for All Transmission Line Circuits (Index 1): 1 Af Fvc,k ' Y .fk Nk i=1 where Fyok = frequency index for the Voltage Class, vc, (units = Forced Outages('Ms) /Transmission Line Circuit). The frequency index equals the average (mean) number of Forced Outages(lms)for all Transmission Line Circuits within a Voltage Class for the calendar year "kn. Nk = number of Transmission Line Circuits in Voltage Class in calendar year "le. See Note 2, Section 4.1.1 of this Appendix C. fk frequency of Forced Outages('ms)for the "it'" Transmission Line Circuit as calculated in accordance with Section 4.1.1 of this Appendix C for calendar year "k". Issued by: Chaves F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 163 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 163 1 No, D vc,k — N Z d fk a,k tal where D►ok = duration index for the Voltage Class (units = minutes/Transmission Line Circuit). The duration index equals the average accumulated duration of Forced Outages""s)for all Transmission Line Circuits within a Voltage Class which experienced Forced Outages'"s) during the calendar year W. Nak = number of Transmission Line Circuits in the Voltage Class for which the Forced Outage('""s) frequency Availability Measure (fik) as calculated in accordance with Section 4.1.1 of this Appendix C is greater than zero for the calendar year "k". See Note 2, Section 4.1.1 of this Appendix C. dk = accumulated duration of Forced Outages("'s) for the "ill " Transmission Line Circuit having a Forced Outage('""s) frequency Availability Measure (fk) greater than zero for calendar year "k" as Calculated in accordance with Section 4.1.1 of this Appendix C. Annual Proportion of Transmission_ Line Circuits with No Forced Outaales"s)(Index U Nk — No,k Pvc,k = N k where Pya,k = index for the proportion of Transmission Line Circuits for the Voltage Class with no Forced Outages(lms) for the calendar year "k". Nk = number of Transmission Line Circuits in Voltage Class for calendar year "k" . See Note 2, Section 4.1.1 of this Appendix C. Nark = number of Transmission Line Circuits in the Voltage Class for which the Forced Outage('ms) frequency Availability Measure (fk) as calculated in Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 154 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 164 accordance with Section 4.1.1 of this Appendix C is greater than zero for the calendar year "k". See Note 2, Section 4.1.1 of this Appendix C. 4.2.2. DEVELOPMENT OF LIMITS FOR CONTROL CHARTS The CL, UCL, LCL, UWL and LWL for the three control charts (Annual Average Forced Outage('" Frequency for All Transmission Line Circuits; Annual Average Accumulated Forced Outage('"'s) Duration for those Transmission Line Circuits with Forced Outages"); and Annual Proportion of Transmission Line Circuits with No Forced Outages(lm$)) on which the annual Availability Measures indices are to be plotted shall be calculated as described below. The CL, UCL, LCL, UWL and LWL for each of the three control charts shall be determined using continuously recorded Forced Outage°""ajdata for the ten calendar year period immediately preceding the date a Transmission Owner becomes a PTO in accordance with the provisions of the Transmission Control Agreement. In the event that a PTO does not have reliable, continuously recorded Forced Outage(") data for this 10 calendar year period, that PTO may determine the control chart limits using data for a shorter period. However, if data for a shorter period are to be used, that PTO shall prepare a brief report to the ISO providing reasonable justification for this modification. This report shall be submitted to the ISO within 90 days after the date a TO becomes a PTO in accordance with the provisions of the Transmission Control Agreement. The ISO shall periodically review the control chart limits and recommend appropriate modifications to each PTO in accordance with this Appendix C. 4.2.2.1. CENTER CONTROL LINES (CLs) The calculation of the CLs for each of the three control charts is similar to the calculation of the annual Availability Measures indices described in Section 4.2.1 of Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 155 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 155 this Appendix C except that the time period is expanded from a single calendar year to ten calendar years, unless a shorter period is justified by a PTO, for the period preceding the date a TO becomes a PTO in accordance with the provisions of the Transmission Control Agreement. To account for this change, a count of Transmission Line Circuit years is included in the equations as shown below to enable derivation of US which represent average performance during a multi -year period. CL for Annual Average Transmi lion Line ('MSS � Circui# Forced Outage Freouen� Y �N^k `y CLf,c=f►k/(L.Nk k=1 i=1 k=1 where CLf,c = center control line value for the Forced Outage") frequencies for each of the Transmission Line Circuits in the Voltage Class for "Y" calendar years prior to the date a TO becomes a PTO. Y = number of calendar years prior to the date a TO becomes a PTO for which the PTO has reliable, continuously recorded Forced Outage'MS) data. Y--10 is preferred. y No y CLdw dk k=1i=I k-1 where CLo,c = center control line value for accumulated Forced Outage(") duration for each of the Transmission Line Circuits in the Voltage Class for "Y"calendar years prior to the date a TO becomes a PTO in which the Forced Outage(IMS) frequency (&) was greater than zero. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 156 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 156 CL for Annual Proportion of Trans!Mj§sion Line Circuits with No Fgng QuWg@§1f) y (Nk — No k ) ._ k=1 CLPvc y I Nk k=I where CLp„, = center control line value for the proportion of Transmission Line Circuits in the Voltage Class with no Forced Outages('ma)for "r calendar years prior to the date a TO becomes a PTO. 4.2.2.2. Calendar Years UCLs, LCLs, UWLs AND LWLs The UCLs, UWLs, LWLs, and LCLs for the control charts for each Voltage Class containing four or more Transmission Line Circuits with Forced Outages (IMS) shall be determined by bootstrap resampling methods as follows: The available historical data for Index 1 and 2 will each be entered into columns. A "seed" is then selected prior to beginning the sampling process. The ISO assigns a number for the "seed" prior to each calendar year's development of the control charts. The "seed" allows the user to start the sampling in the same place and get the same results provided the data order hasn't changed. For Index 1, sampling with replacement will occur for the median number of Transmission Line Circuits per calendar year in a Voltage Class for the time period being evaluated. A sample, the size of which is the median number of all Transmission Line Circuits for the period being evaluated, is taken from the column of actual frequency values for all Transmission Line Circuits. A mean is calculated from this sample and the resulting number will be stored in a separate column. This process will be repeated 10,000 times in order to create a column of sampling means from the historical database. The column of sampling means is then ordered from the smallest Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 167 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 167 to largest means. From this column percentiles are determined for a UCL (99.75), a LCL (0.25), a UWL (97.5), and a LWL (2.5). Thus, for one cycle, the limits are determined by resampling from the historical database, calculating statistics of interest, in this case means, and then estimating appropriate limits from the resampling means. Ten cycles of this same process are necessary to get ten values each of UCLs, LCLs, UWLs, and LWLs. The average for the ten values of each limit is taken to provide the UCL, LCL, UWL, and LWL values used in analyzing annual performance. The procedure is repeated for Index 2, forming means for the median number of Transmission Line Circuits with Forced Outages(l""s)in this Voltage Class for the time period being evaluated. See Bootstrapping - A Nonparametric Approach to Statistical inference (1993) by Christopher Z. Mooney and Robert D. Duval, Sage Publications with ISBN 0-8039-5381-X, and An Introduction to the Bootstrap (1993) by Bradley Efron and Robert J. Tibshirani, Chapman and Hall Publishing with ISBN 0- 412-04231-2 for further information. Consider an example to illustrate how the bootstrap procedure works for one cycle of the ten required. Assume that a Voltage Class has approximately 20 Transmission Line Circuits per calendar year with a history of ten calendar years. Furthermore, assume that about 15 Transmission Line Circuits per calendar year experience Forced Outages(lms). Therefore, there are 10 x 15 =150 Forced Outage(ms) durations available for bootstrap sampling. Place these 150 Forced Outage('""s) durations in a column, say "outdur," in a specified order. The order is automatically provided in the bootstrap algorithm developed by the ISO and made available to the PTO. The bootstrap algorithm will sample 15 rows from "outdur" with replacement. That is, any row may, by chance, be sampled more than once. From these 15 values determine the sample mean and place this in another column, say "boot". Repeat this sampling process 10,000 times adding the new means to "boot". The column "boot" now has 10,000 means from samples of size 15 from the original Forced Outage("O) duration data for this Voltage Class. The next step is to locate the appropriate percentiles from these means for use in determining the control chart limits for one cycle. This is Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 .Tr CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 158 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 168 accomplished by ordering the column "boot" from smallest -to -largest mean and restoring these ordered means in "boot. The percentiles which are needed are 99.75% (UCL), 97.50% (UWL), 2.50% (LWL) and 0.25% (LCL). These are easily estimated from the sorted means by finding the associated rows in the column "boot". For example, LWL will be estimated as the average of the 250th and 251 st rows in column "boot". Likewise the other limits will be determined. Of course, the CL is the actual mean average for 15 Transmission Line Circuits over the ten calendar years using the formulas in Section 4.2.2.1 of this Appendix C. This example is for one cycle. Nine more cycles of this process will establish the more accurate control and warning limits necessary to evaluate a PTO's annual performance. UCLs, LCLs. UWLs and LWLs for Index 1 and 2 for All Other Voltaoe Classes When data for less than four Transmission Line Circuits with Forced Outages(IMS)are available per calendar year in a Voltage Class for fewer than five calendar years, an exhaustive enumeration of all possible selections with replacement may need to be performed. This is because the number of possible samples for bootstrap resampling will be less than the aforementioned 10,000 resampling frequency used for Voltage Classes containing four or more Transmission Line Circuits with Forced Outages(lms)for five or more calendar years. For example, if a Voltage Class has only two Transmission Line Circuits per calendar year for five calendar years, the data base will consist of 2*5 =10 accumulated Forced Outage(ms) durations assuming both Transmission Line Circuits experience one Forced Outage(lms) or more per calendar year. Resampling two values from the column of ten yields only 10**2 = 100 possible means. Thus, bootstrap resampling of 10,000 would over -sample the original data 10,000/100 =100 times. For the general case, let M = the number of accumulated Forced Outage(lms) durations (or Forced Outage('ms) frequencies) from the historical database. If n is the median number of Transmission Line Circuits per calendar year, there are M**n = U possible Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO, 7 First Revised Sheet No. 159 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 159 enumerated means for this Voltage Class. The procedure to determine the appropriate limits for a Voltage Class is to order the column containing "U" enumerated means from smallest to largest means. Then, the UCL, LCL, UWL, and LWL are determined from this vector as described above (i.e., at the 99.75, 0.25, 97.5, and 2.5 percentiles, respectively). UCLs LCLI, UWLs and LWLs for Index I Vyhen Number of TraplMissil2n Line Circuits is > 125 According to standard procedures for proportion control charts for Voltage Classes where the median number of Transmission Line Circuits in service is greater than 125 for any given calendar year, the upper and lower control chart limits (UCL, LCL, UWL, and LWL} for the "I& calendar year are determined using the normal approximation to the binomial distribution. The formulas are: UCL = CLP„c + 3SP„G,k LCL = CLpvc . 3SP„c,k UWL and LWL are calculated by replacing the "3" above with "2n and `SryPvc,k = CL pj1 — CLPvc) / N k where SPrc,k = standard deviation for the annual proportion of Transmission Line Circuits in the Voltage Class with no Forced Outages("')for each "k"'" year of the "Y" calendar years prior to the date a TO becomes a PTO. If LCL or LWL is less than zero, they should be set to zero by default. UCLs. LCLs. UWLs and LWLs for Index 3 when Number of Transmission Line Circuits is less than n_or equal to 125 and areater than or equal to six Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 100 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 160 The UCLs, LCLs, UWLs, and LWLs for the control charts for each Voltage Class shall be based on exact binomial probabilities for those Voltage Classes having equal to or more than six, but less than or equal to 125 median Transmission Line Circuits per calendar year. A customized macro and a statistical software package approved by the ISO creates the proportion control charts. The macro determines the control limits and use of the exact binomial or the normal approximation to the binomial for computing the control chart limits. This macro ensures the UCL and LCL contain about 99.5% and the UWL and LWL contain about 95% of the binomial distribution. The percentile values of the UCL, UWL, LWL, and LCL are respectively 99.75%, 97.5%, 2.5%, and 0.25%. The UCL, UWL, LWL, and LCL are calculated using the following formulas: UCL = (X1+ (P2 - P1)/(P3 - P1) )/ n UWL = ( X1+ (P2- P1)/(P3 - P1) )/ n LWL = (X1+ (P2 - P1)/(P3 - P1) )/ n LCL = (X1+ (P2 - P,)/(P3 - P1) )/ n Where P, = A cumulative binomial probability that if not equal to the P2 value is representing the percentile value that is less than and closest to the 99.75, 97.50, 2.5, and 0.25 percentile values used respectively in the UCL, UWL, LWL, and LCL formulas (e.g., if P, = 0.99529 and is closest to the 99.75 percentile value, from the low side, P, = 0.99529 should be used in the UCL formula). P2 = A cumulative binomial probability equal to the 0.9975, 0.9750, 0.025, and 0.0025 values used respectively in the UCL, UWL, LWL, and LCL above formulas (e.g., P2 = 0.9975 in the UCL formula and = 0.025 in the LWL formula). P3 = A cumulative binomial probability that if not equal to the P2 value is representing the percentile value that is greater than and closest to the 99.75, 97.50, 2.5, and 0.25 percentile values used respectively in the UCL, UWL, LWL, and LCL formulas (e.g., if P3 = 0.99796 and is closest to the Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 161 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Shy No. 161 99.75 percentile value, from the high side, then P3 = 0.99796 should be used in the UCL formula). X, = The number of Transmission Line Circuits with no Forced Outagesams) associated with the P, cumulative binomial probability values used respectively in the UCL, UWL, LWL, and LCL formulas (e.g., if P, = 0.99529 and represents the closest percentile from below the 99.75 percentile for the case where 19 Transmission Line Circuits had no Forced Outages(`m$), then X, = 19 should be used in the UCL formula). n = The median number of Transmission Line Circuits that are in service in a given calendar year. This number remains the same in each of the UCL, UWL, LWL, and LCL formulas. 4.2.3. EVALUATION OF AVAILABILITY MEASURES PERFORMANCE The control charts shall be reviewed annually by the ISO and PTOs in order to evaluate Availability Measures performance. The annual evaluation shall consist of an examination of each of the control charts to determine if one or more of the following four tests indicate a change in performance. The four tests have been selected to enable identification of exceptional performance in an individual calendar year, shifts in longer -term performance, and trends in longer -term performance. Tests • Test 1: The index value for the current calendar year falls outside the UCL or LCL. • Test 2: At least v1 consecutive annual index values fall above the CL or v2 consecutive annual index values fall below the CL. The actual values of v1 and v2 will be output from the bootstrap resampling procedures. The choices for v1 and v2 are designed to keep the probability of these events less than one percent. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 162 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 162 Table 1. Values of v1 and v2 for Percentiles of the CL In Specified Ranges Percentile v1 v2 35 - 39 10 5 40 10 6 41 - 43 9 6 44-46 8 6 47 - 48 8 7 49 - 51 7 7 52 - 53 7 8 54 - 56 6 8 57 - 59 6 9 60 6 10 61 - 65 5 10 Thus, for example, if for a particular Voltage Class the percentile of the historical CL is 55%, this Table indicates that the CL is located at the 55 percentile of all bootstrap means in the "boot" column. From Table 1, v1=6, and v2=8. • Test 3: At least two out of three consecutive annual index values fall outside the UWL or LWL on the same side of the CL. • Test 4: Six or more values are consecutively increasing or consecutively decreasing. Therefore, Test 1 is designed to detect a short-term change or jump in the average level. Tests 2 and 4 are looking for long-term changes. Test 2 will detect a shift up in averages or a shift to a lower level. Test 4 is designed to detect either a trend of continuous increase in the average values or continuous decrease. Test 3 is designed to assess changes in performance during an intermediate period of three calendar years. If Test 3 is satisfied, the evidence is of a decline (or increase) in Availability over a three calendar year period. Together the four tests allow the ISO to monitor the Availability performance of a Voltage Class for a PTO. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 163 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 163 If none of these tests indicate that a change has occurred, performance shall be considered to be stable and consistent with past performance. If one or more of these tests indicates a change then Availability performance shall be considered as having improved or degraded relative to the performance defined by the control chart. Table 4.2.1 provides a summary of the performance indications provided by the tests. The control chart limits may be updated annually if the last calendar year's Availability performance indices did not trigger any of the four tests. If none of the four tests are triggered, the new limits will be constructed including the last calendar year's data. The control chart limits may be modified each year to reflect the number of Transmission Line Circuits in service during that calendar year if necessary. However, it is suggested that unless the number of Transmission Line Circuits changes by more than 30% from the previous calendar year, the use of the median number of Transmission Line Circuits should continue. Consider an example; suppose after the control chart has been prepared for a Voltage Class, next calendar year's data arrives with the number of Transmission Line Circuits 30% higher than the median used in the past. New limits will be generated in order to assess the Availability performance for that calendar year. For the special case where only one Transmission Line Circuit has a Forced Outage(IMS) in a Voltage Class during a calendar year, the assessment process for Index 2 is as follows; if Index 2 for this Transmission Line Circuit does not trigger any of the four tests, no further action is necessary. If, however, one or more of the tests are triggered, then limits for this Transmission Line Circuit for that calendar year should be recalculated based on the historical data for this Transmission Line Circuit alone using an individual and moving range control chart. The only test warranted here is Test 1. More information on the individual and moving range control charts can be found in the user manuals of the statistical software used in creating the control charts Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 I CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 164 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 164 Table 4.2.1 Performance Indications Provided by Control Chart Tests Control Chart T Test Performance Status Indlcatod bx Test Results Number Results Improvement!?!gradation Annual Average Forced Outage(IMS) Frequency 1 value is above the UCL x value is below the LCL when LCL>0 x 2 v1 or more consecutive values above the CL x v2 or more consecutive values below the CL x 3 2 out of 3 values above the UWL x 2 out of 3 values below the LWL x 4 6 consecutive values increasing x 6 consecutive values decreasing x Annual Average Accumulated Forced Outage(') Duration 1 value is above the UCL x value is below the LCL when LCL>0 x 2 v1 or more consecutive values above the CL x v2 or more consecutive values below the CL x 3 2 out of 3 values above the UWL x 2 out of 3 values below the LWL x 4 6 consecutive values increasing x 6 consecutive values decreasing x Annual Proportion Of Transmission Line Circuits with No Forced Outages(w) 1 value is above the UCL x value is below the LCL when LCL>0 x 2 v1 or more consecutive values above the CL x v2 or more consecutive values below the CL x 3 2 out of 3 values above the UWL x 2 out of 3 values below the LWL x 4 6 consecutively increasing values x 6 consecutively decreasing values x Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 165 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 165 4.3. AVAILABILITY REPORTING Each PTO shall submit an annual report to the ISO within 90 days after the end of each calendar year describing its Availability Measures performance. This annual report shall be based on Forced Outagelms) records. All Forced Outage(IMS) records shall be submitted by each PTO to the ISO and shall include the date, start time, end time, affected Transmission Facility, and the probable cause(s) if known. S. MAINTENANCE PRACTICES 5.1. INTRODUCTION These ISO Transmission Maintenance Standards, as they may be periodically revised in accordance with the provisions of the Transmission Control Agreement and this Appendix C, and as they may be clarified by the Maintenance Procedures, shall be followed by each PTO in preparing, submitting, and amending its Maintenance Practices. The Maintenance Practices will provide for consideration of the criteria referenced in Section 14.1 of the TCA, including facility importance. 5.2. PREPARATION OF MAINTENANCE PRACTICES 5.2.1. TRANSMISSION LINE CIRCUIT MAINTENANCE As may be appropriate for the specific Transmission Line Circuits under the ISO's Operational Control, each PTO's Maintenance Practices shall describe the Maintenance activities for the various attributes listed below: 5.2.1.1. OVERHEAD TRANSMISSION LINES • Patrols and inspections, scheduled and unscheduled • Conductor and shield wire • Disconnects/pole-top switches • Structure grounds • Guys/anchors • Insulators Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT • Rights -of -way • Structures/Foundations • Vegetation Management First Revised Sheet No. 166 Superseding Original Sheet No. 166 5.2.1.2. UNDERGROUND TRANSMISSION LINES • Patrols and inspections, scheduled and unscheduled • Cable/Cable systems • Cathodic Protection • Fluid pumping facilities • Terminations • Arrestors • Rights -of -way • Splices • Structures/vaults/manholes • Vegetation Management 5.2.2. STATION MAINTENANCE As may be appropriate for the specific Stations under the ISO's Operational Control, each PTO's Maintenance Practices shall describe Maintenance activities for the various attributes listed below: • Inspections, scheduled and unscheduled • Battery systems • Circuit breakers • Direct Current transmission components • Disconnect switches • Perimeter fences and gates • Station grounds • Insulators/bushings/arrestors • Reactive power components • Protective relay systems • Station Service equipment • Structures/Foundations • Transformers/regulators • Vegetation Management Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 167 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 167 5.2.3. DESCRIPTIONS OF MAINTENANCE PRACTICES Each PTO's Maintenance Practices shall include a schedule for any time -based Maintenance activities and a description of conditions that will initiate any performance - based activities. The Maintenance Practices shall describe the Maintenance methods for each substantial type of component and shall provide any checklists/report forms, which may be required for the activity. Where appropriate, the Maintenance Practices shall provide criteria to be used to assess the condition of a Transmission Facility. Where appropriate, the Maintenance Practices shall specify condition assessment criteria and the requisite response to each condition as may be appropriate for each specific type of component or feature of the Transmission Facility. 5.3. REVIEW AND ADOPTION OF MAINTENANCE PRACTICES 5.3.1. INITIAL ADOPTION OF MAINTENANCE PRACTICES In conjunction with its application to become a PTO, each prospective PTO shall provide to the ISO its proposed Maintenance Practices which comply with the requirements set forth in this Appendix C and Section 14.1 of the Transmission Control Agreement. This information shall provide sufficient detail for the ISO to assess the proposed Maintenance Practices. The ISO shall review the proposed Maintenance Practices and may provide recommendations for an amendment. To the extent there is any disagreement between the ISO and the prospective PTO regarding the prospective PTO's proposed Maintenance Practices, such disagreement shall be resolved by the ISO and prospective PTO so that the ISO and the prospective PTO will have adopted Maintenance Practices, consistent with the requirements of this Appendix C and the Transmission Control Agreement, for the prospective PTO at the time that the ISO assumes Operational Control of the prospective PTO's Transmission Facilities. To the extent there are no recommendations, the proposed Maintenance Practices will be Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 118 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 168 adopted by the ISO and the prospective PTO as the Maintenance Practices for that prospective PTO. 5.3.2. AMENDMENTS TO THE MAINTENANCE PRACTICES 5.3.2.1. AMENDMENTS PROPOSED BY THE ISO Each PTO shall have in place Maintenance Practices that have been adopted by the ISO as set forth in this Appendix C. The ISO shall periodically review each PTO's Maintenance Practices having regard to these ISO Transmission Maintenance Standards and Maintenance Procedures. Following such a review, the ISO may recommend an amendment to any PTO's Maintenance Practices by means of a notice delivered in accordance with Section 26.1 of the Transmission Control Agreement. The PTO may draft amended language in response to the ISO's recommendation. If the PTO exercises its option to draft amended language to the ISO's proposed amendment, the PTO shall so notify the ISO within 30 days after the receipt of notice from the ISO. The PTO will provide the ISO with its proposed amendment language in a time frame mutually agreed upon between the PTO and the ISO. If, after the ISO receives the proposed amendment language from the PTO, the ISO and the PTO are unable to agree on the language implementing the ISO recommendation, then the provisions of Section 5.3.3.2 of this Appendix C shall apply. 5.3.2.2. AMENDMENTS PROPOSED BY A PTO Each PTO may provide to the ISO its own recommendation for an amendment to its own Maintenance Practices, by means of a notice delivered in accordance with Section 26.1 of the Transmission Control Agreement. 5.3.3. DISPOSITION OF RECOMMENDATIONS 5.3.3.1. If the ISO makes a recommendation to amend the Maintenance Practices of a PTO, as contemplated in Section 5.3.2.1 of this Appendix C, that PTO shall have 30 Business Days to provide a notice to the ISO, pursuant to Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO, 7 First Revised Sheet No. 169 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 169 Section 26.1 of the Transmission Control Agreement, stating that it does not agree with the recommended amendment or that it intends to draft the language implementing the amendment, as set forth in Section 5.3.2.1 of this Appendix C. If the PTO does not provide such a notice, the amendment recommended by the ISO shall be deemed adopted. If a PTO makes a recommendation to amend its own Maintenance Practices, as contemplated in Section 5.3.2.2 of this Appendix C, the ISO shall have 30 Business Days to provide a notice to that PTO, pursuant to Section 26.1 of the Transmission Control Agreement, that it does not concur with the recommended amendment. If the ISO does not provide such a notice, then the recommended amendment shall be deemed adopted. Notwithstanding the foregoing, if an amendment proposed by a PTO to its own Maintenance Practices meets the objectives of Section 2.1 of this Appendix C and is submitted in accordance with the requirements in Section 5.2 of this Appendix C, the ISO shall adopt said amendment. If any amendment to a PTO's Maintenance Practices is adopted, the PTO will specify the transition time to implement the adopted amendment so as to ensure the ISO and PTO are clear as to the implementation time frame where Maintenance may be performed under both sets of practices. 5.3.3.2. If the ISO or a PTO makes a recommendation to amend Maintenance Practices and if the ISO or PTO provides notice within the 30 Business Days specified in Section 5.3.3.1 of this Appendix C that the ISO or PTO does not agree with the recommended amendment, the PTO and the ISO shall make good faith efforts to reach a resolution relating to the recommended amendment. If, after such efforts, the PTO and the ISO cannot reach a resolution, the pre-existing Maintenance Practices shall remain in effect. Either Party may, however, seek further redress through appropriate processes, including non -binding discussions at the TMCC and/or the dispute resolution mechanism specified in Section 15 of the Transmission Control Agreement. The PTO may also request, during the initial attempts at resolution and at Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 170 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 170 any stage of the redress processes, a deferral of the ISO recommended amendment and the ISO shall not unreasonably withhold its consent to such a request. Following the conclusion of any and all redress processes, the PTO's Maintenance Practices, as modified, if at all, by these processes, shall be deemed adopted by the ISO, as the Maintenance Practices for that PTO, pursuant to the implementation time frame agreed to between the PTO and the ISO. 5.3.3.3. If the ISO determines, that prompt action is required to avoid a substantial risk to reliability of the ISO Controlled Grid, it may direct a PTO to implement certain temporary Maintenance activities in a period of less than 30 Business Days, by issuing an advisory to the PTO to that effect, by way of a notice delivered in accordance with Section 26.1 of the Transmission Control Agreement. Any advisory issued pursuant to this Section 5.3.3.3 shall specify why implementation solely under Sections 5.3.3.1 and 5.3.3.2 of this Appendix C is not sufficient to avoid a substantial risk to reliability of the ISO Controlled Grid, including, where a substantial risk is not imminent or clearly imminent, why prompt action is nevertheless required. The ISO shall consult with the relevant PTO before issuing a Maintenance advisory. Upon receiving such an advisory, a PTO shall implement the temporary Maintenance activities in question, as of the date specified by the ISO in its advisory, unless the PTO provides a notice to the ISO, in accordance with Section 26.1 of the Transmission Control Agreement, that the PTO is unable to implement the temporary Maintenance activities as specified. Even if the PTO provides such a notice, the PTO shall use its best efforts to implement the temporary Maintenance activities as fully as possible. All Maintenance advisories shall cease to have effect 90 Business Days after issuance by the ISO or on such earlier date as the ISO provides in its notice. Any Maintenance advisories required to remain in effect beyond 90 Business Days shall require a recommendation process pursuant to Section 5.3.3.1 or Section 5.3.3.2 of this Appendix C. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 'r l CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 171 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 171 5.4. QUALIFICATIONS OF PERSONNEL All Maintenance of Transmission Facilities shall be performed by persons who, by reason of training, experience and instruction, are qualified to perform the task. 6. MAINTENANCE RECORD KEEPING AND REPORTING A PTO shall maintain and provide to the ISO records of its Maintenance activities in accordance with this Section 6 of this Appendix C. 6.1. PTO MAINTENANCE RECORD KEEPING The minimum record retention period for Transmission Facilities subject to time based scheduled intervals shall be the designated Maintenance cycle plus two years. The minimum record retention period for all other Transmission Facility Maintenance activities identified through inspection, assessment, diagnostic or another process shall be a minimum of 2 years after the date completed. A PTO's Maintenance records shall, at a minimum, include the: 1) responsible person; 2) Maintenance date; 3) Transmission Facility; 4) findings (if any); 5) priority rating (if any); and 6) description of Maintenance activity performed. 6.2. PTO MAINTENANCE REPORTING Each PTO will submit a Standardized Maintenance Report as outlined in the Maintenance Procedures. The ISO will accept, at the PTO's option, a Standardized Maintenance Report in either electronic or paper form. If a PTO retains records in a manner that includes additional information, such records may be submitted in that manner. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 172 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 172 Each PTO shall provide to the ISO Maintenance records as described in Section 6.1 and as set forth in the Maintenance Procedures. 6.3. ISO VISIT TO PTO'S TRANSMISSION FACILITIES The ISO may visit Transmission Facilities in accordance with Section 18.3 of the Transmission Control Agreement to determine if the Maintenance Practices are being followed by a PTO. 7. ISO AND TRANSMISSION MAINTENANCE COORDINATION COMMITTEE The ISO shall establish and convene a Transmission Maintenance Coordination Committee (TMCC). The TMCC shall develop and, if necessary, revise the Maintenance Procedures, including conveying information to and seeking input from PTOs and other interested stakeholders regarding these Maintenance Procedures and any proposed amendments or revision thereto. The TMCC will also make recommendations on the ISO Transmission Maintenance Standards and any proposed revisions or amendments thereto. The TMCC will convey information to and seek input from the PTOs and other interested stakeholders on these ISO Transmission Maintenance Standards and any proposed revisions or amendments thereto. The TMCC will also perform any other functions assigned in this Appendix C. Although the role of the Transmission Maintenance Coordination Committee is advisory in nature, the ISO will strive to achieve a consensus among committee members. 8. REVISION OF ISO TRANSMISSION MAINTENANCE STANDARDS AND MAINTENANCE PROCEDURES 8.1 REVISIONS TO ISO TRANSMISSION MAINTENANCE STANDARDS The ISO, PTOs, or any interested stakeholder may submit proposals to amend or revise these ISO Transmission Maintenance Standards. All proposals shall be initially submitted to the TMCC for review in accordance with this Appendix C. Any revisions to Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 173 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 173 these ISO Transmission Maintenance Standards shall be made only upon recommendation by the TMCC and only in accordance with the provisions and requirements of the Transmission Control Agreement and this Appendix C. 8.2 REVISIONS TO AND DEVIATIONS FROM MAINTENANCE PROCEDURES The ISO or any PTO may submit proposals to the TMCC to amend or revise the Maintenance Procedures. Any deviations from the Maintenance Procedures should be held to a minimum and will be negotiated between the ISO and the affected PTO. 9. INCENTIVES AND PENALTIES 9.1 DEVELOPMENT OF A FORMAL PROGRAM The TMCC shall periodically investigate and report to the ISO on the appropriateness of a formal program of incentives and penalties associated with Availability Measures. Should the TMCC .ever recommend that the ISO adopt a formal program of incentive and penalties, the formal program will only be adopted as set forth in Section 9.2 of this Appendix C. 9.2 ADOPTION OF A FORMAL PROGRAM Any formal program of incentives and penalties adopted by the ISO in connection with matters covered in Section 14 of the Transmission Control Agreement or this Appendix C, shall be established only: 1) with respect to Availability Measures; 2) upon recommendation of the TMCC as set forth in Section 9.1 of this Appendix C; 3) by express incorporation into this Appendix C in accordance with the provisions of the Transmission Control Agreement; and 4) upon approval by the FERC. Nothing in this Appendix C shall be construed as waiving or limiting in any way the right of any party or PTO to oppose or protest any formal program of incentives and penalties filed, proposed or adopted by the ISO and/or FERC or any portion thereof. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 174 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original, Sheet No. 174- 9.3 IMPOSITION OF PENALTIES IN THE ABSENCE OF A FORMAL PROGRAM In the absence of a formal program of incentives and penalties, the ISO may seek FERC permission for the imposition of specific penalties on a PTO on a case -by -case basis in the event that the relevant PTO 1) exhibits significant degradation trends in Availability performance due to Maintenance, or 2) is grossly or willfully negligent with regard to Maintenance. 9.4 NO WAIVER Nothing in this Appendix C shall be construed as waiving the rights of any PTO to oppose or protest any incentive, penalty or sanction proposed by the ISO to the FERC, the approval by FERC of any specific penalty or sanction, or the specific imposition by the ISO of any FERC approved penalty or sanction on the PTO. 9.5 LIMITATIONS ON APPLICABILITY TO NEW PTOS For a new PTO, the Availability Measures system needs to be used and updated during a five calendar year phase in period, as set forth in Section 4.2 of this Appendix C, to be considered in connection with any formal program of incentives and penalties associated with Availability Measures. 10. COMPLIANCE WITH OTHER REGULATIONS/LAWS Each PTO shall maintain and the ISO shall operate Transmission Facilities in accordance with Good Utility Practice, sound engineering judgment, the guidelines as outlined in the Transmission Control Agreement, and all other applicable laws and regulations. Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: • October 10, 2006 ,1 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 216 THIRD REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 215 SLINGS 2&3 REQUIREMENTS FOR OFFSITE Revised as of October 10, 2006 1. OVERVIEW The preferred source of electrical power for the San Onofre Nuclear Generating Station (SONGS) electrical loads (safety -related and non safety -related) is the offsite pourer supply or 230 kV grid. The offsite power supply is sometimes referred to as the preferred power supply in the applicable regulatory documents. The offsite power supply is considered "Operable" with respect to the SONGS Operating License and Technical Specifications when it can provide sufficient capacity and capability to supply electrical loads needed to safely shut down the reactor and mitigate certain specified accident scenarios. The offsite power supply is considered "Inoperable" with respect to the SONGS Operating License and Technical Specifications if it is degraded to the pant that it cannot provide sufficient capacity and capability to supply electrical loads needed to safely shut down the reactor and to mitigate the effects of an accident at SONGS. It is a necessary condition of the SONGS Operating License and Technical Specifications that the offsite power supply be Operable at all times. if the offsite power supply is declared Inoperable, action must be taken to shut down an online SONGS unit(s) and, for an offline unit, to suspend activities as required by the SONGS Operating License and Technical Specifications. This level of degradation that would result in inoperability can be caused by an unstable offsite power system, or any condition which renders the offsite power supply unavailable to safely shutdown the units or to supply emergency electrical loads. Since accident scenarios for which the SONGS plant is designed can result in a unit trip, it is imperative that this trip not impair the operability of the offsite power supply. If both SONGS units are online and one unit trips (due to an accident or otherwise), the non -tripped unit will provide local voltage support to the SONGS switchyard, and 230 kV system voltage will remain within the required range. In cases where one SONGS unit is online and one unit offline, the offsite power supply must be sufficiently robust to survive a trip of the online unit and meet the SONGS voltage requirements in the post -trip condition. A dual unit trip is not the limiting condition since a plant accident is not postulated simultaneous with a dual unit trip. System Operating Procedures (see Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 216 THIRD REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 216 Reference 9 below) and programs shall be in place to ensure that various system operating conditions (generating unit outages, line outages, system loads, spinning reserve, etc.), including multiple contingency events, are evaluated and understood, such that impaired or potentially degraded grid conditions are recognized, assessed and communicated to the SONGS Control Room. The SONGS switchyard is made up of the Southern California Edison Company (SCE) switchyard and the San Diego Gas & Electric Company (SDG&E) switchyard. Unless specifically stated otherwise, SONGS switchyard requirements contained in this document apply to both the SCE switchyard and the SDG&E switchyard. II. REQUIREMENTS Note: This section identifies the operational requirements for the SONGS offsite power supply. These requirements are part of the SONGS design basis and licensing basis. Failure to meet these requirements may render the offsite power supply Inoperable, thus requiring the operating SONGS units) to shutdown. Failure to meet these requirements must be communicated to SCE and the SONGS Control Room for operability determination as soon as practicable, but In any case, within one hour. Changes in the operation of the transmission network that conflict with these requirements must have prior approval by SCE. Note. Specific requirements, procedures, operating bulletins, division orders, and analysis that support or provide the basis for the specific operational requirements may be revised periodically subject to prior approval of the affected parties. 1. Nine transmission lines into the SONGS switchyard are normally in service. Any increase or decrease in the number of lines into the SONGS switchyard requires prior approval of SCE. (Reference 7 below) No line may be removed from service for greater than 30 days without prior notification to SCE. At least two independent transmission lines (one from SCE and one from SDG&E) between the transmission network (grid) and SONGS switchyard shall be in service at all times. (References 1, 2, 3, 4, 7, 8 below) 2. With both San Onofre units off-line, the SONGS offsite power source shall be capable of providing 158 MW and 96 MVAR to SONGS for normal operation and for shutting down the units during plant Design Basis Accident (DBA) conditions. (References 9, 10 below) 3. The minimum grid voltage at the SONGS switchyard shall be maintained at or above 218 kV. In the event of a system disturbance that can cause the voltage to dip below 218 kV, including the trip of a SONGS unit, the grid voltage shall Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2066 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 217 THIRD REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 217 recover to 218 kV or above within 2.5 seconds. (References 9, 10, 12, 13, 18 below) 4. The following initiating events shall not result in the loss of grid stability or availability: a. The loss of a SONGS Unit (with the other unit already oftline), or b. The loss of any generating unit on the SCE and SDG&E grids, or C. The loss of any major transmission circuit or intertie on the SCE and SDG&E grids, or d. The loss of any large load or block of load (e.g., due to a bus section outage) on the SCE and SDG&E grids. (References 2, 3, 4, 8 below) 5. The maximum grid voltage at the SONGS switchyard shall be maintained at or below 234 kV. (References 10, 11, 18 below) 6. The normal operating voltage of the SONGS switchyard shall be maintained at 229 W. The SONGS switchyard voltage shall not exceed 232 kV unless required to preserve transmission network integrity. (References 10, 11, 18 below) 7. The 3 limiting conditions for SONGS offsite power supply operability are defined as follows: 1. One SONGS unit is off- line, and 2. One of the critical line (s) outages, in GCC Operating Procedure, OP-13: SONGS Voltage (reference 19) occurs, and 3. VAR flows north and south of SONGS are above the threshold levels for the existing combined SCE and SDG&E import level as defined by the nomograms referenced in the GCC Operating Procedure, OP-1 3: SONGS Voltage. Based on these nomograms and SONGS ol''fline unit's status, whenever limiting conditions 1 and 2, as set forth in this Requirement 7, occur, the ISO (or the SCE Grid Control Center (SCE GCC), as directed by the ISO) shall, as soon as practicable but, in any case, within one hour of the event, perform an evaluation of system conditions to determine, whether or not the SONGS off site power supply Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 J CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 218 THIRD REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 218 remains Operable as defined herein. If the SONGS offsite power supply Is Inoperable or cannot be determined to be Operable as defined herein, the ISO (or the SCE GCC, as directed by the ISO) shall notify the SONGS Control Room immediately of entry into the event. Subsequent to notification, the SONGS Control Room shall declare the offsite power supply Inoperable (in anticipation of losing the second SONGS unit) and shall declare the time period within which the on-line unit will have to initiate shutdown if conditions are not corrected. The time period shall be within 1 to 24 hours, based on the SONGS plant and equipment conditions. In order to ensure the continued ability to meet the 3 limiting conditions identified above in this Requirement 7, the following six requirements (a-f) must be met: a. Systems studies shall be performed and updated based on changing grid conditions (load growth, etc.) to identify critical conditions that could render the offsite power supply Inoperable. b. Procedures and programs shall be in effect to ensure that the SONGS Control Room is notified as soon as practicable but, in any case, within one hour of an event that renders the offsite power supply Inoperable. C. Grid conditions that are more severe with respect to SONGS switchyard voltage, or are otherwise unanalyzed, shall render the offsite power supply Inoperable. d. Auditable records of current system studies shall be made available to SCE as needed to demonstrate compliance with regulatory requirements. Study results, including revisions and updates, shall be formally transmitted to SCE. e. Study results and conclusions shall be assessed at least annually and updated, if needed, based on changing grid conditions. Results of the annual assessments shall be formally transmitted to Vice President Nuclear Engineering and Technical Services, San Onofre Nuclear Generating Station. (References 1, 2, 19, and 21 below) f. System studies shall consider the interconnections between SCE, SDG&E, and other utilities in the Wester Electricity Coordinating Council (WECC). (Reference 7 below) Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 219 THIRD REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No.219 8. In the event of loss of the SONGS offsite power: Note: SONGS 2 and 3 are required by NRC regulations to be able to safely cope with a loss of all AC power (Station Blackout) for a maximum of four hours. The four hour coping duration is based on the expectation that at least one source of AC power (offsite transmission line or onsite diesel generator) will be restored to the blacked -out unit within the four hours to ensure the proper functioning of systems required for plant safety. a. Highest possible priority shall be given to restoring power to the SONGS switchyard. Procedures and training should consider several potential methods of transmitting power from black -start capable units to the SONGS switchyard. This includes such items as nearby gas turbine generators, portable generators, hydro generators, and black -start fossil power plants. (References 15, 26, 28 below) b. Should incoming lines to the SONGS switchyard be damaged, highest priority shall be assigned to repair and restoration of at least one line into the SONGS switchyard. C. Repair crews engaging in power restoration activities for SONGS shall be given the highest priority for manpower, equipment, and materials. d. Formal programs and procedures shall be in place to effect items a, b and c above. (References 14, 15, 16, 17, 26, 27 below) 9. Grid frequency shall be maintained at 60 Hertz (nominal). A trip of one SONGS unit shall not cause the grid frequency to dip below 59.7 Hertz. SCE and SDG&E shall comply with the WECC Coordinated Off -Nominal Frequency Load Shedding and Restoration Plan. (References 7, 20 below) 10. SCE and SDG&E Bulk Power Transmission System Reliability Criteria as described in the SONGS Updated Final Safety Analysis Report (UFSAR) shall be maintained. It is recognized that the SCE and SDG&E Bulk Power Transmission System Reliability Criteria as described in the SONGS 2&3 Updated Final Safety Analysis Report may be revised from time to time. In the event the reliability criteria are revised, a system assessment and/or study (as described under specification 7) shall be performed to determine if the revised reliability criteria adversely impact grid reliability and availability as defined in this specification. Results of the assessment and/or study together with a copy of the revised reliability criteria shall be provided to SCE. Changes in grid operation based on the revised criteria and associated studies shall not be implemented without prior approval of SCE. (Reference 7 below) Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 220 THIRD REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 220 11. Patrol and inspection of SCE and SDG&E transmission lines, to ensure that the physical and electrical integrity of transmission components are maintained, shall be performed as required by the SONGS UFSAR or in accordance with the current ISO approved Overhead Electric Transmission Line Maintenance Practice, whichever requirement is more stringent. (Reference 7 below) 12. Line insulators on lines which cant' power from the plant to the grid shall be washed as required by the SONGS UFSAR or on an appropriate wash cycle in accordance with the current ISO approved Overhead Electric Transmission Line Maintenance Practice, whichever requirement is more stringent. The purpose and frequency of which is proven to prevent line outages that may result from flashovers due to accumulated contamination. (Reference 7 below) 13. Maintenance, testing and calibration of SCE and SDG&E station equipment and protective relays shall be performed as required by the SONGS UFSAR or in accordance with the current ISO approved Electrical Station Maintenance Practice, whichever requirement is more stringent. (Reference 7 below) 14. Preventive maintenance and testing of SONGS switchyard batteries shall be performed in accordance with IEEE 450-1985 or IEEE 450-2002 subsequent to SONGS converting its battery maintenance program to IEEE 450-2002 requirements. (Reference 7, 23 below) 15. Updates to applicable portions of Section 8.0, Electric Power of the SONGS UFSAR shall be provided annually to facilitate periodic updates to the UFSAR by SONGS that are required by 10CFR50.71(e). Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 .r CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 221 THIRD REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 221 A REFERENCES (Current approved revision except as noted) 1) SONGS 2&3 Operating License and Technical Specifications, Section 3.8, Electrical Power Systems 2) 1 OCFR50 Appendix A, General Design Criterion 17 (GDC-17), Electrical Power Systems 3) NUREG 75/087, Standard Review Plan Revision 1, Section 8.2, Offsite Power System 4) NUREG 0800, Standard Review Plan Revision 2, Section 8.2, Offsite Power System 5) NUREG 0800, Standard Review Plan Revision 2, Branch Technical Position ICSB-11 (PSB), Stability of Offsite Power Systems 6) NUREG 0712, SONGS 20 Safety Evaluation Report, Section 8.0, Electric Power Systems 7) SONGS 2 & 3 Updated Final Safety Analysis Report, Section 8.0, Electric Power 8) ANSI/IEEE Std. 765-2002 Preferred Power Supply for Nuclear Power Generating Stations 9) SONGS Design Calculation E4C-082, System Dynamic Voltages During Design Basis Accident 10) SONGS Design Calculation E4C-090, Auxiliary System Voltage Regulation 11) SONGS Design Calculation &C-092, Short Circuit Studies 12) SONGS Design Calculation E4C-098, 4 kV Swgr Protective Relay Setting 13) DBD-S023-120, SONGS Design Basis Document, 6.9KV, 4.16KV and 480V Electrical Systems 14) 90051, SONGS Station Blackout Analyses 15) NUMARC 87-00 Guidelines and Technical Bases for NUMARC initiatives Addressing Station Blackout at Light Water Reactors 16) Letter from M. 0. Medford (SCE) to the Document Control Desk (NRC), dated April 17, 1989, Subject: "Response to 10 CFR 50.63, 'Loss of all Alternating Current Power,' San Onofre Nuclear Generating Station Units 1, 2 and 3" issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 �M CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 222 THIRD REPLACEMENT TRANSMISSION CONTROL, AGREEMENT Superseding Original Sheet No. 222 17) Letter from F. R. Nandy (SCE) to the Document Control Desk (NRC), dated May 1, 1990, Subject: "Supplemental Response to 10 CFI? 50.63, 'Loss of All Alternating Current Power,' Station Blackout (TAC No. 685991600), San Onofre Nuclear Generating Station Units 1, 2, and 3" 18) System Operating Bulletin 17 Appendix, System Voltage Control for San Onofre Nuclear Generating Station 19) GCC Operating Procedure, OP-013: SONGS Voltage 20) System Operating Bulletin 113, San Onofre 220 kV System Separation 21) Regulatory Guide 1.93, Revision 0, Availability of Electric Power Sources 23) SCE Division Order 60.20, Storage Batteries 26) System Operating Bulletin 1-A, Thermal Station Start-up and Power System Restoration 27) System Operating Bulletin 254, Emergency Orders --San Onofre Nuclear Generating Station 220 kV 28) SDG&E Control Procedure 1150, Capacity & Energy Emergencies - SDG&E System Emergencies 29) IEEE Std, 450-1985 IEEE Recommended Practice for Maintenance, Testing, and Replacement of large Lead Storage Batteries for Generating Stations and Substations 30) IEEE Std. 450-2002 IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead -Acid Batteries for Stationary Applications Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 225 TRANSMISSION CQNTROL AGREEMENT APPENDIX F NO� TILES Issued by: Anthony Ivancovich, Senior Regulatory Counsel Issued on: November25, 2002 Effective: January 1, 2003 �P CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT N� 1C ES California Independent System Operator Name of Primary Representative: Roni Reese Title: Senior Contraacts Analyst Address: 151 Blue Ravine Road City/State2ip Code: Folsom, California 95630 Email Address: rreese@oiso.com Phone: (916) 608-7027 Fax No: (916) e08-7292 Name of Alternative First Revised Sheet No. 226 Superseding Original Sheet No. 226 Representative: Philio D. Pettinaill Title: Manager of Infrastructure Policy & Contracts Address: 151 Blue Ravine Road City/State2ip Code: Folsom, California 95630 Email Address: ggettinaill0caiso.com Phone: (916) 608-7241 Fax No: (916) 608-7292 Name of Representative for Notices of Access Charge and Transmission Revenue Requirement Matters: Deborah A. Le Vine Title: Director of Market Services Address: 151 Blue Ravine Road City/State2ip Code: Folsom California 95630 Email Address: dievinel-caiso.com Phone: (916) 351-2144 Fax No: (916) 351-2267 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Pacific Gas and Elloctric Company First Revised Sheet No. 227 Superseding Original Sheet No. 227 Name of Primary Representative: Rod Maslgwski Title: Director, Electric SyftM Qverations Address: 77 Beale Street. Room 1526 City/State/Zip Code: San Francisco, CA 94105 , Email Address: RJM80r)ge.com Phone: 415-973-1_218 Fax No: 415-973-3341 Name of Alternative Representative: Steve Metaque Title: Doctor, Electric Transmission Rates Address: 77 Beale Street, Room 1339 City/State/Zip Code: San Francisco, CA 94105 Email Address: WIVIdOwe.com Phone: 415-973-6545 Fax No: 415-973-9174 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 228 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 228 San Diego Gas & Electric Company Name of Primary Representative: Scott Peterson Title: Director — Electric Grid Qperations Address: 9060 Friars Ropy City/State/Zip Code: San Diego. CA 92108 Email Address: sgeterson@,senrautilities.com Phone: 619-725-8639 Fax No: 619-725-8616 Name of Alternative Representative: Caroline Winn Title: Director — Electric Transmission and Distribution: Planning Address: 8316 Century Park Court City/State/Zip Code: San Diego, CA 92123 Email Address: cwinn@serr-prautilities.com Phone: 858-654-1648 Fax No: 858-654-8244 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION First Revised Sheet No. 229 FERC ELECTRIC TARIFF NO.7 Superseding Original Sheet No. 229 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Southern California Edison Company Nam of Primary Representative: Title: Address City/State/Zip Code: Email Address: Phone: Fax No: Nam of Alternative Representative: Title: Address: City/State/Zip Code: Email Address: Phone: Fax No: Ronald L. Utzinger Senior Vice President, Transmission &, Distribution 2244 Walnut Grove Ave. Q04 Rosemead, California 91770 ronald.litzingeasce.com (626) 302,-2243 (626) 302-2782 John R. Fielder SCE President 2244 Walnut Grove Ave. G04 Rosemead„�Califomia 91770 iohn.fielderD-sce com (626) 302-3440 (,626) 302-2970 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION First Revised Sheet No. 230 FERC ELECTRIC TARIFF NO.7 Superseding Original Sheet No. 230 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT City of Vernon Name of Primary Representative: Donal O'Callaghan Title: Director of Light and Power Address: 4305 Santa Fe Avenue City/State/Zip Code: Vernon, California 90058 Email Address: docallaTghan _cimernon.cams Phone: (323) 583-8811 extension 834 Fax No: (323) 826-1425 Name of Alternative Representative: Abraham Alemu Title: Resource Engineer Address: 4305 Santa Fe Avenue City/State2ip Code: Vernon California 90058 Email Address: aalemu _cimemon.cg.us Phone: ,(323) 583-8811 extension 250 Fax No: (323,) 826-1425 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 231 City of Anaheim Name of Primary Representative: Sheryll A. Schroeder Title: City Clerk Address: 200 S. Anaheim Blvd. City/State2ip Code: Anaheim, California 92805 Email Address: sschroedereDanaheim.net Phone: (714) 765-5645 Fax No: (714) 765-4105 Name of Alternative Representative: Title: Address: City/State2ip Code: Email Address: Phone: Fax No: Marcie L. Edward Public Utilities General Manager 201 S. Anaheim Blvd., Site 1101 Anaheim California 92805 medwards(a-)-anahei m. net (714) 765-5173 (714) 765-4138 Issued by: Anthony Ivaneovich, Senior Regulatory Counsel Issued on: November 25, 2002 Effective: January 1, 2003 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO, 7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 232 City of Azusa Name of Primary Representative: Joseph Hsu Title: Director of Utilities Address: 729 N. Azusa Avenue City/State/Zip Code: Azusa CA 91702 Email Address: ihsuQ-ci.azusa.ca.us Phone: (626) 812-5171 Fax No: (626) 334-3163 Name of Alternative Representative: Bob Tang Title: Assistant Director of Resource Management Address: 729 N. Azusa Avenue City/StatelZip Code: Azusa,_CA 91702 Email Address: btangD-ci.azusa.ca.us Phone: (626) $1275214 Fax No: (626) 334-3163 Issued by: Anthony Ivancovieh, Senior Regulatory Counsel Issued on: November25, 2002 Effective: January 1, 2003 e CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION First Revised Sheet No. 233 FERC ELECTRIC TARIFF NO.7 Superseding Original Sheet No. 233 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT City of Banning Name of Primary Representative: James D. Earhart Title: Electric Utility Director Address: 176 E. Lincoln St. City/StatefZip Code: Banning, California 92220 Email Address: aearhartOW banning.ca.us Phone: (9511922-3266 Fax No: (951) 849-1550 Name of Alternative Representative: Fred Mason Title: Power Resource & Revenue Admin. Address: 176 East Lincoln Street City/State/Zip Code: Banning, California 92220 Email Address: fmason0ci.bannina.ca.us Phone: (951) 922-3265 Fax No: (951) 849-1550 Issued by: Charles F. Robinson, Vitae President and General Counsel Issued on: August 11, 2006 0Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION First Revised Sheet No. 234 FERC ELECTRIC TARIFF NO.7 Superseding Original Sheet No. 234 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT City of Riverside Name of Primary Representative: David H. Y nit Title: Public 11tilities General Manager Address: 3900 Main Street City/State/Zip Code: Riverside ,QA 92522 Email Address: dwright riv rsideca.aov Phone: (951) 826-5784 Fax No: (951) 369-0548 Name of Alternative Representative: Gary L. Nolff Title: Assistant Director -Resources Address: 3900 Main Street City/State/Zip Code: Riverside CA 92522 Email Address: gnolffD-riversideca.aov Phone: (951) 826-5113 Fax No: (951) 369-0548 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 r# r, CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION Second Revised Sheet No. 235 FERC ELECTRIC TARIFF NO.7 Superseding First Revised Sheet No. 235 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Trans -Elect NTD Path 15, LLC Name of Primary Representative: Robert Q. Dickerson Title: Executive Vice Presidept & Chief Operating Officer Trans -Elect NTD Path 15, LLC Address: 720 S. Tyier Street, Suite 232 City/State/Zip Code: Amarillo Texas 79101 Email Address: bdikkerson a ntdpath1511c.com Phone: (806) 322-3278 Fax No: (806) 322-3279 Name of Altemative Representative: James H. Drzemiecki Title: Vice President —Acquisitions. Rates & Regulation Trans -Elect, Inc. Address: 1850 Centennial Park Drive, Suite 480 City/State/Zip Code: Reston, VA 20191 Email Address: ihdrzemiecki0trans-elect.com Phone: (703) 563-4358 Fax No: (703) 563-4331 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 First Revised Sheet No. 236 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 236 Western Area Power Administration, Sierra Nevada Region Name of Primary Representative: James D. Keselburg Title: Regional Manager Address: 114 Parkshore Drive City/State/Zip Code: Folsom, CA 95630-4710 Email Address: keselbrg@w pa.aov Phone: (916) 3534418 Fax No: (916) 985-1930 Name of Alternative Representative: Thomas R. Boyko Title: Power Marketing Manager Address: 114 Parkshore Drive City/State/Zip Code: Folsom, CA 95630-4710 Email Address: BoykoD-waoa.aov Phone: (916) 353-4421 Fax No: (916) 985-1931 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 r r# CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT City of Pasadena Name of Primary Original Sheet No. 237 Representative: Ms. Phyllis E. Currie Title: General Manager City of Pasadena Water and Power Department Address: 150 S. Los Robles, Suite 200 City/State2ip Code: Pasadena, CA 91101 Email Address: pcurrie@cityofpasadena.net Phone: (626) 744-4425 Fax No: (626) 744-4470 Name of Alternative Representative: Mr. Steven K. Endo Title: Resource Planning Manager City of Pasadena Water and Power Department Address: 150 S. Los Robles, Suite 200 City/State2ip Code: Pasadena, CA 91101 Email Address: sendo@cityofpasadena.net Phone: (626) 744-6246 Fax No: (626) 744-6432 Issued by: Anthony ivancovich, Senior Regulatory Counsel Issued on: December 23, 2004 Effective: January 1. 2005 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO.7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Trans Bay Cable LLC Name of Primary Representative: David S. Parquet Title: Vice President Address: Trans Say Cable LLC c% Babcock & Brown LP 2 Harrison Street, 6t' Floor City, State, Zip Code San Francisco, CA 94105 Email address: david. a�rquetobabcockbrown.com Phone: (415) 512-1515 Fax No: (415) 267-1500 Name of Alternative Representative: Judith A. Hall Title: Associate General Counsel Address: c/o Babcock & Brown LP 2 Harrison Street, 6t' Floor City, State, Zip Code San Francisco, CA 94105 Email address: iudith.hall@babcockbrown.com Phone: 415-512-1515 Fax No: 415-267-1500 Original Shot No. 238 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: Upon notice after October 10, 2006 dee 8fl(elal,cc d k`l7-1� Ju LIGHT AND POWER DEPARTMENT INTER -DEPARTMENT MEMORANDUM DATE: August 3, 2006 VO: Jeff Harrison, Chief Assistant City Attorney FROM: Donal O'Callaghan, Director of Light and Power SUBJECT: TCA Amendment Execution Package Attached for your review and City Council's approval is the Transmission Control Agreement (TCA) Amendment Execution Package, which the ISO proposes to file with FERC on August 11, 2006. Please return the 26 executed original signature pages to the Light and Power Department at which point we will forward to the ISO. If you have any questions or concerns regarding this matter please contact me. DOC:yt Attachments: TCA Amendment Execution Package. C: Bruce V. Malkenhorst, Acting City Clerk (without attachments) Document Control File 0 INTEROFFICE MEMORANDUM LIGHT AND POWER DEPARTMENT Date 81212006 To: Donal O'Callaghan, Director of Light and Power From: Abraham Alemu, Resource Engineer` Subject: TCA Amendment Execution Package Attached is an execution package of amendment to the Transmission Control Agreement (TCA) the ISO proposed to file with the FERC on August 11, 2006. The amendment primarily concerns adoption of the ISO Transmission Maintenance Standard (Section 14 and Appendix C to the TCA), and updates to individual Participating Transmission Owner's entitlements and encumbrances (Appendices A and B to the TCA). There are no changes to Vernon's Appendix A and Appendix B. Vernon Staff has participated in conference calls to review the proposed amendment. Vernon has no issues with the proposed changes. ISO has requested each PTO to sign 26 original signature pages and return in time to make the filing of the amendment with FERC on August 11, 2006. Staff recommends the City approve the TCA amendment and return 26 executed original signature pages to the ISO. cc' j Jay LIGHT AND POWER DEPARTMENT 2I q (, INTER DEPARTMENT MEMORANDUM DATE: August 3, 2006 (:;�?— - TO: Jeff Harrison, Chief Assistant City Attorney FROM: Donal O'Callaghan, Director of Light and Power SUBJECT: TCA Amendment Execution Package � ,,C 'fb Y-L_A 1� Attached for your review and City Council's approval is the Transmission Control SH ° 10 Agreement (TCA) Amendment Execution Package, which the ISO proposes to fil with FERC on August 11, 2006. Please return th 26 executed original signature pa e o the Light and Power Department at which point we will forward to the ISO. If you have any questions or concerns regarding this matter please contact me. DOC:yt Attachments: TCA Amendment Execution Package. C: Bruce V. Malkenhorst, Acting City Clerk (without attachments) Document Control File 1 11 INTEROFFICE MEMORANDUM LIGHT AND POWER DEPARTMENT Date 8/2/2006 To: Donal O'Callaghan, Director of Light and Power From: Abraham Alemu, Resource Engineer -(;0- Subject: TCA Amendment Execution Package Attached is an execution package of amendment to the Transmission Control Agreement (TCA) the ISO proposed to file with the FERC on August 11, 2006. The amendment primarily concerns adoption of the ISO Transmission Maintenance Standard (Section 14 and Appendix C to the TCA), and updates to individual Participating Transmission Owner's entitlements and encumbrances (Appendices A and B to the TCA). There are no changes to Vernon's Appendix A and Appendix B. Vernon Staff has participated in conference calls to review the proposed amendment. Vernon has no issues with the proposed changes. ISO has requested each PTO to sign 26 original signature pages and return in time to make the filing of the amendment with FERC on August 11, 2006. Staff recommends the City approve the TCA amendment and return 26 executed original signature pages to the ISO. d a CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 68 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 68 31. SIGNATURE PAGE CITY OF VERNON CITY OF VERNON has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 8th day of August, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Vernon) Appendix B (Vernon) Appendix C Appendix D Appendix E Appendix F CITY OF VERNON By:ti EONIS C. MA BURG, Mayor ATTEST: 1 BRUCE V. MALKENHORST, JR. Acting City Clerk APPROVEJ? AS TO FORM: Jeff (MhrHkbn, Chief Assistant City Attorney Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 Page 1 of 1 Romero, Debbie From: Romero, Debbie Sent: Thursday, May 17, 2007 1:11 PM To: Alemu, Abraham Subject: TCA Amendment Execution Package CAISO Hi Abraham. Have you received the counterpart signature pages back yet from the CAISO? If you have them or when you get them, I need the originals for the agreement file. I will be sending you a copy of the resolution and a copy of the memos pertaining to the above for your reference. Thanks and have a great day. 5/17/2007 RECEIVED A COPY OF THE AGREEMENT FROM LIGHT & POWER Ch California ISO VYour Link to Power November 7,' 2006 Donal O'Callaghan City of Vernon 4305 Santa Fe Avenue Vernon, CA 90058 Via FedEx delivery Participating TO Representatives: L g� C) A+ California Independent System Operator Corporation NOV 0 g 2006 Enclosed for your files are two fully executed sets of the signature pages for insertion into the execution version of your Transmission Control Agreement among the Participating TOs and prospective New Participating TOs and the California Independent System Operator. Also, please note that the integrated version of each of the amended components of the TCA has now been posted on the CAISO website (www.caiso.com). The TCA can be found under the headings "Operations Center"/"Legal and Regulatory"/"Contracts and Agreements"/"Transmission Control Agreement" at the following CAISO website address: http://www.caiso.com/docs/2005/10/08/2005100817510214319.html. Please let me know if you need further assistance or have any questions. I can be reached by phone at (916) 608-7027 or by email at rreese@caiso.com. Kindest regards, 40tL V 4X Roni L. Reese Sr. Contract Analyst Enclosures DISTRIBUTION ;or c^eu�ew [v}�,Qt� _ Cn i www.caiso.com 1151 Blue Ravine Road I Folsom, CA 95630 1916.351.4400 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Fourth Revised Sheet No. 64 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 3`d Revised Sheet No. 64 27. SIGNATURE PAGE CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION California Independent System Operator Corporation has caused this Transmission Control Agreement to be executed by its duly authorized representative on this �t, Aay of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendices A Appendices B Appendix C Appendix D Appendices E Appendix F CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION 151 Blue Ravine Road Folsom, California 95630 by Jir Vic Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Fourth Revised Sheet No. 65 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 3`d Revised Sheet No. 65 28. SIGNATURE PAGE PACIFIC GAS AND ELECTRIC COMPANY Pacific Gas and Electric Company has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 7th day of August, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (PG&E) Appendix B (PG&E) Appendix C Appendix D Appendix E (Diablo Canyon) Appendix F PACIFIC GAS AND ELECTRIC COMPANY 77 Beale Street San Francisco, California 94105 by: Stewart M. Ramsay Vice President, Asset Management & Electric Transmission Issued by: Charles F. Robinson, Vice President and General Counsel a Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Third Revised Sheet No. 66 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 2nd Revised Sheet No. 66 29. SIGNATURE PAGE SAN DIEGO GAS & ELECTRIC COMPANY San Diego Gas & Electric Company has caused this Transmission a Control Agreement to be executed by its duly authorized representative on this day ofc�, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (SDG&E) Appendix B (SDG&E) Appendix C Appendix D Appendix E (SONGS) Appendix F SAN DIEGO GAS & ELECTRIC COMPANY 8330 Century Park Court San Diego, California 92123 by: James Avery Senior Vice President of San Diego Electric Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Third Revised Sheet No. 67 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 2"d Revised Sheet No. 67 30. SIGNATURE PAGE SOUTHERN CALIFORNIA EDISON COMPANY Southern California Edison Company has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 24t" day of July, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Edison) Appendix B (Edison) Appendix C Appendix D Appendix E (SONGS) Appendix F SOUTHERN CALIFORNIA EDISON COMPANY 2244 Walnut Grove Avenue Rosemead, California 91770 by: Y Ronald L. Litzinger Senior Vice President, Transmission & Distribution Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 68 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 68 31. SIGNATURE PAGE CITY OF VERNON CITY OF VERNON has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 8t" day of August, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Vernon) Appendix B (Vernon) Appendix C Appendix D Appendix E Appendix F CITY OF VERNON By:i�� F LEONIS C. MALEWRG, Mayor ATTEST: BRUCE ALKENHORST, JR. Acting City Clerk APPROVED AS TO FORM: Jeffff f��ikop, Chief Assistant City Attorney Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 69 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 69 32. SIGNATURE PAGE CITY OF ANAHEIM CITY OF ANAHEIM has caused this Transmission Control Agreement to be executed by its duly authorized representative on this '''day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Anaheim) Appendix B (Anaheim) Appendix C Appendix D Appendix F ATTEST: APPROVED AS TO FORM: CITY OF ANAHEIM By: Marcie L. Edwards Public Utilities General Manager APPROVED AS TO FORM: JACK t HI . CITY ATTORNEY By Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 70 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 70 33. SIGNATURE PAGE CITY OF AZUSA CITY OF AZUSA has caused this Transmission Control Agreement to be executed by its duly authorized representative on h�klay of 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Azusa) Appendix B (Azusa) Appendix C Appendix D Appendix F CITY OF AZUSA By. Diane Chagnon Mayor Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 71 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 71 34. SIGNATURE PAGE CITY OF BANNING CITY OF BANNING has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of , 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Banning) Appendix C Appendix D Appendix F CI A Y:, Randy Ans me City Manager ATTEST: Marie C Ideron, City Clerk APPROVED AS TO FORM: 1� J , City Attorney NOVbtA-, %qWK Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 72 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 72 35. SIGNATURE PAGE CITY OF RIVERSIDE CITY OF RIVERSIDE has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 17th day of October 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Riverside) Appendix B (Riverside) Appendix C Appendix D Appendix F CITY OF RIVERSIDE 3900 Main Street, 4t" Floor Riverside, California 92622 By: �� 4e_� Bradle . Hudson, City Manager ATTEST: ity Cler APPROVED AS TO FORM: c pe—i-i — Deputy City Attorney Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 Third Revised Sheet No. 72A SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 2"d Revised Sheet No. 72A 36. SIGNATURE PAGE TRANS -ELECT NTD PATH 15, LLC TRANS -ELECT NTD PATH 15, LLC has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 28t" day of July, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Trans -Elect) Appendix C Appendix D Appendix F Trans -Elect NTD Path 15, LLC 1850 Centennial Park Drive Suite 480 Reston, VA 20191 mow. _ By: f e 1---'' Robert D. Dickerson Executive Vice President Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF. NO. 7 Second Revised Sheet No. 72B SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding 1st Revised Sheet No. 72B 37. SIGNATURE PAGE WESTERN AREA POWER ADMINISTRATION, SIERRA NEVADA REGION WESTERN AREA POWER ADMINISTRATION, SIERRA NEVADA REGION has caused this Transmission Control Agreement to be executed by its duly authorized representative on thisl d y of VA , 2006 and thereby Ij incorporates the following Appendices in this Agreement: Appendix A (Western) Appendix C Appendix D Appendix F Western Area Power Administration, Sierra Nevada Region Sierra Nevada Rye an 114 Par ei Drive Fo1916ffi, CA 95630-471.0 Im ®r-�616111-11 Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 First Revised Sheet No. 72C SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Superseding Original Sheet No. 72C 37. SIGNATURE PAGE CITY OF PASADENA CITY OF PASADENA has caused this Transmission Control Agreement to be executed by its duly authorized representative on this day of 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Pasadena) Appendix B (Pasadena) Appendix C Appendix D Appendix F City of Pasadena Water and Power Department 150 S. Los Robles, Suite 200 Pasadena, CA 91101 City Ma APPROVED AS TO FORM: >' 1 This day of ., 2Q..& ATTEST: _71TY CLERK Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: October 10, 2006 CALIFORNIA INDEPENDENT SYSTEM OPERATOR CORPORATION FERC ELECTRIC TARIFF NO. 7 SECOND REPLACEMENT TRANSMISSION CONTROL AGREEMENT Original Sheet No. 72D 39. SIGNATURE PAGE TRANS BAY CABLE LLC TRANS BAY CABLE LLC has caused this Transmission Control Agreement to be executed by its duly authorized representative on this 2nd day of August, 2006 and thereby incorporates the following Appendices in this Agreement: Appendix A (Trans Bay Cable LLC) Appendix C Appendix D Appendix F Trans Bay Cable LLC c/o Babcock & Brown LP 2 Harrison Street, 6t" Floor San Francisco, CA 94105 Tel: (415) 512-1 15 Fax: (415) 2500 By: —�_ David Parquet Vice President Trans Bay Cable LLC Issued by: Charles F. Robinson, Vice President and General Counsel Issued on: August 11, 2006 Effective: Upon notice after October 10, 2006