§ 16-107.9

Illinois § 16-107.9

• Jurisdiction: Illinois
• Topic: REGULATION
• Ch. 220: UTILITIES
• Act 220 ILCS 5/: Public Utilities Act.
• Art.: Article XVI - Electric Service Customer Choice And Rate Relief Law Of 1997

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(This Section may contain text from a Public Act with a delayed effective date ) Sec. 16-107.9. Virtual power plant program. (a) As used in this Section: "Aggregator" means a third-party entity that participates in the program, other than the electric utility or its affiliate, that (i) represents and aggregates the load of participating customers who collectively have the ability to deploy 100 kilowatts or more of deployment of eligible devices and (ii) is responsible for performance of the aggregation in the program. "Battery" means a behind-the-meter energy storage device and associated equipment that operate together to fulfill program requirements. "Commission" means the Illinois Commerce Commission. "Customer" means an active electric service account holder of a utility. "Direct participant" means a customer that enrolls in the program directly with the utility, rather than participating in the program through an aggregator. "Distributed energy resource" has the meaning set forth in Section 16-107.6. "Distributed energy resources management system" means a platform that may be used by distribution system operators or utilities to integrate grid resources, such as distributed energy resources, into system operations. "Eligible device" means a customer or third party-owned distributed energy resource that satisfies the requirements for participation in the program as specified in the relevant program rider. "Eligible device" also means any device that can be controlled to respond to pricing, provide services, including decrease peak electricity demand or shift demand from peak to off-peak periods, or inject power to the grid. "Eligible device" includes, but is not limited to, behind-the-meter energy storage systems, smart thermostats, electric vehicle batteries, including fleets, and distributed renewable energy devices paired with one or more energy storage systems. "Emergency event" means an event called by the utility with fewer than 24 hours notice. "Energy storage system" has the meaning set forth in subsection (a) of Section 16-107.6. "Enrolled customer" means a customer that participates in the program through either an aggregator or as a direct participant. "Enrolled device" means an enrolled customer's eligible device, as specified in the relevant tariff. "Enterprise distributed energy resources management system" means a platform operated by the electric utility that interfaces with a grid-edge distributed energy resources management system to integrate distributed energy resources into utility electric system operations. "Grid-edge distributed energy resources management system" means a platform owned by a party other than the electric utility that may be used to integrate distributed energy resources. "Grid event" means a grid condition for which the utility schedules or remotely dispatches enrolled devices to respond to, as specified in the grid service opportunities for each tariff. "Grid service" means a capacity, energy, or ancillary service that supports grid operations. "Participating customer" means an aggregator or a direct retail customer, as defined in Section 16-102, with one or more eligible devices. "Performance payment" means a payment made to the participant based on the performance of an enrolled device providing a grid service during a grid event. "Performance payment rate" means the compensation rate paid to participants for providing a particular grid service during a grid event. "Smart inverter" has the meaning set forth in subsection (a) of Section 16-107.6. "Upfront payment" means a one-time payment made at the time of enrollment. "Virtual power plant" means an aggregation of behind-the-meter distributed energy resources operated in coordination to provide one or more grid services. (b) The General Assembly finds that: (1) virtual power plants are dynamic load management and energy supply resources that can support grid operations, reduce ratepayer costs, and achieve other important public policy goals; (2) virtual power plants can reduce demand for grid supplied electricity during peak periods, shift electricity consumption out of peak periods, make renewable energy generated during off-peak periods available for use during peak periods, supply energy to the grid at desired times, provide frequency regulation, voltage support, and other ancillary services, reduce strain on the distribution system, manage localized peaks, improve system resiliency and reliability, and provide other grid services; (3) virtual power plants can facilitate and optimize the utilization of electrical generation from wind and solar energy to help utilities increase hosting capacity and integrate more renewable energy resources; (4) virtual power plants can reduce costs to ratepayers by utilizing customer-sited resources to provide grid services, avoiding or reducing reliance on fossil-fuel fired peaker plants, avoiding or deferring the need to construct new and more costly grid scale resources, optimizing the use of existing assets, and avoiding or deferring distribution and transmission system upgrades and other grid investments; (5) virtual power plants can promote equity by reducing costs for all ratepayers, expanding access to distributed energy resources among low-income and moderate-income customers through improved distributed energy resource finance ability, and providing other important co-benefits, including reduction in emissions of greenhouse gases and other pollutants, especially in environmental justice and other disadvantaged communities that host fossil fuel generation plants; (6) the United States Department of Energy estimates that the United States could deploy 80 to 160 gigawatts of virtual power plants by 2030, a tripling of current levels, to support the rapid electrification of vehicles and homes and provide on the order of $10,000,000,000 in ratepayer savings annually. The deployment of virtual power plants can provide energy cost savings and other benefits to the people of Illinois; (7) there are significant barriers to deployment and operation of virtual power plants, including the need for statutory and regulatory guidance and support, greater consistency in virtual power plant programs across regulatory jurisdictions, and for utility commitments to incorporate the use of virtual power plants into system operations and long-term resource planning; (8) it is in the public interest to advance customer choice and leverage the expertise of private, non-utility entities to advance innovation and implement cost-effective clean energy solutions; and (9) the policy of Illinois shall be to maximize the use of virtual power plants comprised of customer-owned and third party-owned distributed energy resources to deliver system services and other benefits through utility administered virtual power plant programs in accordance with the provisions of this amendatory Act of the 104th General Assembly. (c) No later than December 31, 2028, the Commission shall approve at least one virtual power plant tariff for each electric utility serving more than 300,000 customers in the State as of January 1, 2023. Each utility shall file a tariff or tariffs for approval no later than December 31, 2027 to allow retail customers in the electric utility's service areas to participate in a virtual power plant program proposal consistent with the provisions of this Section. The Commission shall provide opportunities for stakeholders to provide input on the virtual power plant programs proposed for implementation by each utility, which the Commission shall take into consideration in its review of each utility's filing. No later than one year after the utility's filing, the Commission shall approve or modify and approve each utility's virtual power plant program proposal for immediate implementation by the utility. (d) The virtual power plant program filed under subsection (c) shall be developed for implementation through a tariff offering with standard terms and conditions for participation. The virtual power plant program tariff shall allow for customers with battery storage, non-battery storage and electric vehicle technologies to enroll the devices in the program through aggregators or directly with the utility. The virtual power plant program tariff shall: (1) provide a mechanism to incorporate existing programs, such as smart thermostat demand-response or electric vehicle charging programs currently offered by the utility, under the virtual power plant program framework; (2) provide grid services opportunities for each eligible technology that customers and aggregators may provide, which shall include, at minimum, reducing the utility's applicable capacity and transmission obligations and capturing daily wholesale energy arbitrage opportunities through provision of grid services; (3) provide additional functions and grid service opportunities that the Commission determines are supportive of efficient planning and operation of the electrical grid, including: (A) minimizing the use of fossil fuels at peak times; (B) local peak demand reductions; (C) locational value; (D) the avoidance or deferral of local transmission or distribution upgrades or capacity expansion; (E) voltage support and other ancillary services; and (F) emergency grid services; (4) provide operational parameters, which shall include, at a minimum: (A) minimum and maximum numbers of grid events for which the utility may require dispatch from the enrolled distributed energy resources; (B) months of the year that grid events may occur; (C) days of the week that grid events may occur; (D) times of day that grid events may occur; (E) maximum duration of grid events; and (F) minimum day-ahead advance notification requirement of grid events, except for emergency events, as applicable; (5) include provisions for aggregators to participate in the virtual power plant program, participate in the utility's distributed energy resource management system as available, automatically enroll and manage their customers' participation, receive dispatch signals and other communications from the utility, deliver performance measurement and verification data to the utility, and receive virtual power plant program payments directly from the utility; (6) include provisions that provide a standardized process for any eligible aggregator to enroll in the program and authorize the eligible aggregators to manage individual customer device participation without additional authorizations from the utility; (7) include provisions that allow a participating customer with multiple eligible devices to enroll the technologies either directly without an aggregator or through one or more aggregators in applicable programs under the tariff approved under this Section, provided that no particular device is accounted for more than once; (8) include provisions for direct participant customers to participate with the utility's distributed energy resource management system as available, receive dispatch signals and other communications from the utility, deliver performance measurement and verification data to the utility, and receive virtual power plant program payments directly from the utility. Any provisions implementing this subpart that necessitate the installation of equipment to enable direct participation via the utility shall apply to customers who elect to participate as a direct participant and shall not be required of customers who participate via an aggregator or to customers who do not participate in the virtual power plant program; (9) provide for measurement and verification of battery non-battery, and electric vehicle technologies performance directly at the device without the requirement for the installation of an additional meter; (10) include upfront payment or performance payment compensation mechanisms for the peak reduction service, as well as for non-battery and electric vehicle technologies as the Commission deems appropriate. The performance payment shall be based on the average capacity provided during grid events. The Commission shall approve additional compensation mechanisms as it determines appropriate for other grid services provided under the battery, non-battery and electric vehicle riders. The virtual power plant program shall not assess penalties for non-performance; provided, however, that the Commission may approve reasonable mechanisms to disenroll customers for continued non-performance; (11) enable low-to-moderate income customers, community-driven community solar projects, and customers whose electric service has not been declared competitive pursuant to Section 16-113 as of July 1, 2011 located in equity investment eligible investment communities to receive a higher upfront enrollment payment. The Commission shall coordinate with State energy officials and departments to make funding from federal programs and such other sources as may be available for use in providing higher upfront payments to customers classes as may be approved by the Commission in accordance with this subsection; (12) provide that the performance payment rate applicable at the time of enrollment shall be for 5 years, after which time the participant may reenroll at the then applicable performance payment rate for an additional 5-year term; (13) provide for a transition of customers from the scheduled dispatch program described in Section 16-107.6 to the virtual power plant program; and (14) allow enrolled customers to participate in other applicable interconnection tariffs and grid service programs outside the virtual power plant program, so long as it does not result in double-counting of benefits for the same grid services. (e) The Commission may adopt other reasonable requirements for participation consistent with this subsection, provided that collateral from an aggregator shall not be required for participation. (f) The utility may contract with a third party-owned distributed energy resource management system provider to assist with program implementation; however, implementation shall not be delayed due to the lack of utility-owned distributed energy resource management system capabilities or third party-owned distributed energy resource management system capabilities. (g) The utility shall not send or receive dispatch signals directly to or from any participating customer represented by an aggregator for an event under the virtual power plant program described in this Section. (h) Participating aggregators shall have capabilities to receive event signals from utilities or utility-contracted distributed energy resources management system providers. (i) Utilities shall recover reasonably and prudently incurred costs to facilitate the virtual power plant program approved under subsection (c), including, but not limited to, distributed energy resource management systems provider and other service contract costs, operations and maintenance expenses, information technology costs, and other costs, expenses, and investments that the Commission finds necessary and prudent for the development and implementation of the program. The utility shall recover the cost of virtual power plant program upfront payments and performance payments and such other payments made to participants through the tariff filed pursuant to subsection (h) of Section 16-107.6. (j) No later than January 31 of each year, each utility shall file an annual report that includes, but is not limited to: (1) the total capacity enrolled in each program rider developed in accordance with the requirements of Section, broken down by technology type, customer class, and aggregator and direct participant status for each grid service opportunity offered in the prior calendar year; (2) recommendations to increase participation in the virtual power plant program; and (3) any other information that the Commission may require. (k) Each utility shall amend existing tariffs and procedures that limit the ability of customers to participate in providing grid services under the program, such as limitations on charging energy storage devices with grid energy or exporting energy to the grid from battery discharge. (l) The tariffs approved by the Commission shall not reflect any additional charges, fees, or insurance requirements imposed on those owning or operating demand-response technologies beyond those imposed on similarly situated customers that do not own or operate demand-response technologies. (m) As a condition of participating in the programs described in this Section, prior to enrollment of a customer by an aggregator, the aggregator shall disclose the following: (1) the payments, expressed as an amount or a formula, to be provided to the customer; (2) between the aggregator and customer, who is responsible for paying penalties or fees; and (3) between the aggregator and customer, who is responsible for posting collateral, if required. Any tariff authorized by this Section shall incorporate the requirements under this subsection and shall require the electric utility to establish a complaint and Commission notification process and, on order of the Commission, suspend any aggregator repeatedly or egregiously violating such requirements.

Legislative History

(Source: P.A. 104-458, eff. 6-1-26.)