Why Duke Energy’s PowerPair Pilot Program Should Be Expanded

Why It Matters

PowerPair demonstrates that modest ratepayer incentives can unlock massive private capital, delivering low‑cost, quickly deployable capacity and reshaping utility resource strategies amid rising demand and regulatory pressure.

Key Takeaways

• PowerPair enrolled 6,297 customers, adding 54 MW solar and 72 MW storage
• $48.6 M incentives leveraged $227 M private solar‑storage investment
• Ratepayer cost per MW is ~ $361k for solar, $403k for storage
• PowerPair solar is ~80% cheaper than Duke’s new gas plant per MW
• Duke’s model selected additional PowerPair resources in 12 of next 15 years

Pulse Analysis

Utilities across the United States are confronting a perfect storm: surging electricity demand from data centers, rising wholesale prices, and the need to keep rates affordable. Traditional responses—building new gas plants, transmission lines, and substations—are capital‑intensive, time‑consuming, and place most financial risk on ratepayers. Duke Energy’s PowerPair pilot offers a contrasting approach by incentivizing customers to install rooftop solar paired with battery storage, effectively turning homeowners into distributed power assets that can be dispatched via a virtual power plant. This model aligns with broader trends toward decentralization and grid resilience, providing immediate capacity without the lengthy permitting cycles that burden conventional projects.

Financially, PowerPair’s leverage is striking. With $48.6 million in public incentives, the program has catalyzed $227 million in private investment, achieving a $1‑to‑$3.70 return on public dollars. The per‑megawatt cost to ratepayers—approximately $361,000 for solar and $403,000 for storage—is dramatically lower than the $2.36 million per MW Duke plans for a new combined‑cycle gas plant. This cost differential underscores the economic advantage of demand‑side resources, especially when utilities face pressure to fund multi‑billion‑dollar infrastructure upgrades. By shifting capital out of the rate base, PowerPair reduces long‑term debt service and mitigates the risk of cost overruns that ultimately flow to consumers.

The strategic implications extend to integrated resource planning (IRP). Duke’s own modeling showed that, even within a limited scenario, additional PowerPair resources would be selected in 12 of the next 15 years, highlighting the cost‑effectiveness of distributed energy resources (DERs) in meeting peak demand. Expert analyses suggest that a more aggressive deployment could quadruple the program’s capacity, further compressing the need for new fossil‑fuel plants. Policymakers and regulators should therefore treat DER pilots like PowerPair not as experimental add‑ons but as essential infrastructure components that deliver speed, lower cost, and reduced risk. Scaling such programs could reshape utility business models, accelerate decarbonization, and protect ratepayers from escalating energy bills.