The detailed requirements for both types of EC are set out in Section 40. The main requirement is resource adequacy and the elements of this program are described below: The decision approved by the California Public Utilities Commission (CPUC) in October requires that non-resource-related RA imports be themselves integrated into the CAISO market. But according to CAISO and other parties, such as the California Community Choice Association (CalCCA), it is changing the RA rules without providing sufficient evidence. ISOs coordinate, monitor and monitor the functioning of the electrical system, usually within a single U.S. state, but sometimes in several states. ISOs also act as market operators in the wholesale trade. The first major change is the increase in the share of renewable energy – as intermittent resources grow on the grid, the CPUC is fighting to ensure that charging units meet ra standards for all hours of the day. A second change is the shift from a system with investor access providers as a dominant pantograph to a system in which the load shifts to community choice aggregators and direct access providers. The main objective of the transmission plan is to identify and describe the best restriction solutions in the controlled grid. Transmission solutions include both new transmission equipment, upgrades or additions of existing transmission equipment proposed, taken into account and/or specified in the overall transmission plan during Phase 2 to meet the needs identified by CAISO. Alternatives to transmission solutions are called non-transmission solutions. Solutions that meet an identified need can be either transmission or non-transmission solutions.
CAISO will analyze the need for transmission solutions in accordance with the methods and criteria set out in Section 24, the Transmission Control Agreement and applicable business practice manuals. The overall transmission plan will identify transmission equipment that meets the requirements to be included in the transmission plan and the transmission solutions needed (1) to maintain system reliability; (2) to meet the requirements of an ease of interconnecting location-limitation resources; (3) maintaining the simultaneous feasibility of long-term revenue rights allocated for crr overload; (4) are identified as additional components or extensions to LGIP network upgrades (large generator interconnection procedures) pursuant to Clause 220.127.116.11; (5) compliance with requirements and guidelines of the state, municipalities, counties and federal policies, including standards for renewable portfolios; and (6) reduce congestion costs, production costs, transmission losses or other electrical supply costs resulting from improved access to low-cost resources. Each participating TO enters into the transmission control agreement with CAISO. In addition to the transformation of existing rights covered in point 16.1.4 and with the exception of Clause 18.104.22.168, the new participating NB must ensure operational control of all equipment and authorizations that: (1) meet the functional criteria of ferC for determining which transmission devices should be placed under the operational control of CAISO; (2) meet the criteria set out by the CAISO Board of Directors, which define the transmission equipment for which CAISO should take operational control; and (3) are the subject of reciprocal agreements between CAISO and the participating TOs.