NYSEG and RG&E C&I demand response and battery economics

NYSEG and RG&E are separate regulated utilities owned by Avangrid. For businesses the split matters in two places: the rate each pays under its own tariff, and the program prices, which differ by a few cents. Program rules, enrollment and annual reporting are shared.

Every deep dive on this site has one feature that changes how its economics read. For NYSEG and RG&E business customers it is an empty auction. New York’s utilities pay for flexibility in two ways: systemwide programs every summer, and multiyear Dynamic Load Management (DLM) contracts. Elsewhere in upstate New York, DLM contracts carry the best prices, because they target overloaded feeders.

At NYSEG and RG&E, Term-DLM and Auto-DLM offer an incentive rate of $25.50 per kW-year plus $0.50 per kWh under three- to five-year contracts (NYSEG RFP). They drew no bids for any summer from 2021 through 2026, and the Distribution Load Relief Program (DLRP) reservation price is $0, so it has no enrollments (NYSEG and RG&E). A business here earns from CSRP, NYISO and its own bill. The value of local grid relief shows up instead in NYSEG’s own procurements: a bulk storage solicitation and a non-wires alternative for the Liberty area (Liberty area RFP).

Yes, within limits. New York separates services: the utility pays for relief on its own system, and NYISO pays for statewide capacity and energy. A site can be paid for both, as long as no one pays twice for the same kilowatt of the same service.

The key ruling dates to 2015. NYSEG, RG&E and Central Hudson argued that paying hourly-pricing customers in CSRP would be a double payment. The PSC disagreed: customers may enroll in both CSRP and SCR, and avoided wholesale capacity value should be left out of CSRP pay when another program already provides it (PSC order). Aggregators such as CPower market the stack (CPower).

Stacking needs care, depending on M&V methodology. CSRP and SCR both measure reductions against customer baselines from interval data; a battery that shaves the same afternoon peak every day lowers its own baseline and shows less event reduction.

Demand charges are worth several times any program. NYSEG’s SC2 general service rate charges $18.04 per kW-month on monthly peak demand (NYSEG rates), about $216 per kW-year if a battery shaves the same peak every month. CSRP adds about $34 at NYSEG and $35 at RG&E, and SCR about $28 before the aggregator’s share. Capacity hit a record $7.90 per kW-month in May and June 2026 (Potomac Economics), so SCR pay swings with the auction.

NYSERDA pays retail storage incentives for batteries that cut demand charges or join demand response, at $175 per kWh in the current Rest of State block (NYSERDA via Central Hudson). On a hypothetical 100 kW / 400 kWh battery that is $70k.

The site’s line above is only half of the deal. The developer pays the full $240k, carries maintenance, insurance and performance risk, and prices all of it into the contract to earn a return on its capital (Morgan Lewis). Third-party storage contracts usually run 15 years or more (Peak Power), and lenders treat 15- to 20-year terms as financeable (Illinois Power Agency). The chart below values each deal from the developer’s side.

With 25% of savings left to the site, a 15-year deal covers about 85% of the developer’s cost on our model. At the modeled cost, a developer cannot earn 8% and still leave the site a share of demand savings. Battery-service offers are not priced the other way around, as a fee on top of handing over the savings: shared-savings providers promote a guaranteed share from day one (Gridwealth Electric), and Peak Power’s projects in Westchester, New York, split bill savings and market revenue with the building owner (NYSERDA case study). A deal that cannot fund a share is usually not offered at all. A guaranteed 15% share would need an installed cost about 22% lower, near $187k, or a larger site where cost per kWh falls; providers such as Peak Power focus on facilities with more than 1 MW of load (Peak Power’s overview). The battery-service line above shows that 15% share. NYSERDA’s upfront incentive and a high demand charge still make NYSEG one of the stronger upstate cases for a business battery that the site owns, even without a DLM contract.

An exporting battery has another path: the Value Stack, New York’s compensation for distributed energy, whose Alternative 3 capacity rate for NYSEG is about $5.06 per kW-month (Gaiergy). It does not combine with selling the same exports to NYISO.

The two utilities received requests for almost 500 MW of new load in 2024 (Avangrid’s Senate testimony). The future of VPP to grow at scale will depend on multiple assets in unison at any given site: building controls, thermal storage, EV charging and batteries, dispatched together. For businesses, the next steps are a DLM price that attracts bids, NYISO’s Order 2222 rules at the end of 2026, and final rate orders that set the next demand charges.

Compare: the National Grid C&I deep dive for DLM contracts that do clear, and the Con Edison C&I deep dive for New York City’s higher capacity prices.