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    • Affected system impacts of generator interconnection
      Interconnecting generation facilities can cause reliability concerns on directly connected and adjacent electric systems. The ISO tariff addresses these situations at a high level. Through this initiative, the ISO proposes processes and principles that should be included in the Business Practice Manual for Generator Interconnection Procedures to address these impacts. These changes will then be vetted through the BPM change management process.
    • Aliso Canyon gas-electric coordination
      Phase 1 of this initiative addressed the gas-electric market coordination concerns raised by the limited operations of the Aliso Canyon gas storage facility. The resulting provisions were approved by FERC and will sunset on November 30, 2016. Aliso Canyon Phase 2 will evaluate and propose to either retire, extend or adjust the interim measures approved for the summer period and will file with FERC to seek authority to retain the needed measures through the winter period. Phase 3 proposes to extend the temporary market and operational tools currently in place so that they remain in effect beyond November 30, 2017. Phase 4 proposes to further extend the measures for an additional year.
    • Alternative dispute resolution committee tariff amendment
      The California ISO tariff places responsibility for administering and coordinating the ISO's process for alternative dispute resolution (ADR) with a committee of the Board of Governors. The committee is required to maintain lists of arbitrators and mediators, process and publish information about ADR activities and compile procedures for arbitration. The purpose of this stakeholder process is to consider a tariff amendment that would – consistent with the practices of other ISOs and RTOs – relieve the ISO Board of alternative dispute resolution responsibility and place it under management's supervision.
    • Amendment 60 implementation plan
      On November 11, 2007 the Federal Energy Regulatory Commission (FERC) issued an “Order on Rehearing” in the Amendment 60 proceeding in Docket ER04-835 (Rehearing Order). The Rehearing Order, among other things, confirmed FERC's earlier finding that “Must Offer” commitments to address the Miguel constraint should be treated as zonal, rather than local. In addition, FERC found that commitments to address the South of Lugo constraint should also be treated as zonal, rather than local.
    • Ancillary services forced buy back
      The ancillary services forced buy back mechanism reduces ancillary service awards and self-provisions by the amount that is unavailable due to transmission constraints or plant limitations. Participants whose resources are subject to forced buy backs currently retain their capacity payments, which increases the cost of ancillary service procurements. This initiative seeks to align the settlement of ancillary services forced buy backs with existing rules of unavailable ancillary service capacity.
    • Ancillary services procurement in HASP and dispatch logic
      To prepare for the new market launch, the California ISO filed and received approval from the Federal Energy Regulatory Commission (FERC ) to defer the procurement of ancillary services in hour-ahead scheduling process (HASP), and to procure any required incremental ancillary services after the day-ahead market in the 15-minute Real-Time Pre-Dispatch (RTPD) process. The ISO submitted the Deferred Function Amendment Filing to FERC on October 31, 2008, and indicated that it anticipated reverting back to hour-ahead procurement of ancillary services six to nine months after the new market go-live. Under this initiative, the ISO considers reverting to ancillary services procurement in HASP and proposes solutions to dispatch energy from operating reserves procured from non-dynamic system resources in the hour ahead.
    • Approval of transmission elements under $50 million
      The tariff allows ISO management to approve transmission projects expected to cost less than $50 million that are identified in the annual planning process. The ISO proposes to extend its tariff provisions to also include any transmission elements under $50 million. This will enable the ISO to conduct competitive solicitations for smaller, needed transmission elements on accelerated timelines and avoid delays caused by trying to meet the Board of Governors approval process.
    • Administrative pricing rules
      This initiative will examine tariff provisions regarding market intervention in the event of significant system emergencies and the settlement implications of force majeure events. The ISO committed to this process in its FERC approved petition to waive tariff provisions for setting administrative prices and settling real-time market transactions related to the September 8, 2011 Pacific Southwest power outage.