FERC Order 2222

The short version

FERC Order 2222, issued in September 2020, required every FERC-jurisdictional grid operator — CAISO, NYISO, ISO-NE, PJM, MISO, and SPP — to revise market rules so that aggregations of distributed energy resources can participate in wholesale capacity, energy, and ancillary services markets. The minimum aggregation size is 100 kW. The intent: unlock the value of small distributed resources (rooftop solar, behind-the-meter batteries, demand response, EV charging, controllable building loads) by allowing them to be bundled and competed against utility-scale generation.

What Order 2222 actually requires

Each FERC-jurisdictional ISO must establish a tariff allowing DERAs (Distributed Energy Resource Aggregators) to register as wholesale market participants. The tariff must accommodate physical and operational characteristics of various DER types — generation, storage, demand response, energy efficiency, and EV charging. Aggregations must meet minimum size of 100 kW. The ISO must establish coordination protocols among the grid operator, aggregator, distribution utility, and relevant retail regulator. Critically, Order 2222 prohibits states from broadly excluding DERs from wholesale market participation, though states retain authority over individual DER interconnection.

The structural challenge: a DER aggregator must coordinate with three different parties — the wholesale market (ISO), the local distribution utility, and the state retail regulator — and meet performance standards while doing so. This complexity has delayed implementation as each ISO works through stakeholder processes to define telemetry requirements, double-counting prevention rules, distribution coordination protocols, and settlement procedures.

Implementation status by ISO

CAISO has implemented Order 2222, building on its pre-existing DER Aggregation program operational since 2021. CAISO requires aggregations to operate within a single Sub-LAP, with telemetry standards for aggregations exceeding 10 MW or providing ancillary services. NYISO targets full Order 2222 compliance by end of 2026, building on a DER aggregation program that has been operational since 2021. ISO-NE targets November 1, 2026 for energy market participation, with capacity market participation beginning February 1, 2027 for the 2028/2029 capacity year.

PJM has been the slowest large ISO — its third compliance filing pushed implementation to February 2028. MISO is implementing in phases: Phase 1 by June 2027, Phase 2 by June 2029. SPP targets Q2 2030. ERCOT is not subject to Order 2222 because it falls outside FERC jurisdiction (Texas operates a separate grid not connected to the eastern or western interconnections), but Texas has implemented its own DER aggregation framework through Public Utility Commission of Texas pilot programs.

What this means for commercial DER owners

For commercial and industrial facilities with behind-the-meter solar, battery storage, demand response capability, or controllable loads, Order 2222 creates a new revenue pathway. Through a DERA, the facility's DER can participate in wholesale capacity auctions, day-ahead and real-time energy markets, frequency regulation, operating reserves, and other services — earning revenue streams beyond simple retail rate offset.

The catch: actual revenue depends on local market conditions, the DERA's bidding strategy, and how DERA payments compare to alternative state retail programs. In many regions, behind-the-meter incentives (net metering, demand response retail programs, SGIP-style state subsidies) currently pay more than wholesale market participation through a DERA. This is changing as capacity prices in PJM, NYISO, and ISO-NE rise to record highs — making wholesale capacity payments increasingly competitive with retail program payments. C&I facilities with substantial DER fleets should evaluate both pathways as implementation progresses in their region.