Aspen Ideas: Climate | Lights On, Bills Low: Building the Grid We Need
The United States is confronting its most rapid surge in electricity demand in two decades, a trend that is reshaping the nation’s power system and prompting an urgent reassessment of how the grid is financed, regulated and expanded. The acceleration is being driven by a wave of new, electricity-intensive uses—most notably data centers that support artificial-intelligence and cloud-computing workloads—as well as broader electrification of industry and transportation.
In the Midwest, the utility serving northern Illinois, KMED, has seen its customer load shift from a decade of flat consumption to annual growth of 2-4 percent, pushing regional peak demand toward unprecedented levels and exposing gaps in generation, transmission and market design.
A Grid Under Pressure
Panelists at a recent expert round-table—including former Federal Energy Regulatory Commission (FERC) member Allison Clemens, Resources for the Future president Billy Piser, KMED chief executive Gil Kenyonus and University of Chicago climate economist Michael Greenstone—agreed that the surge represents both a challenge and an opportunity.
“The power sector has been steady and boring for the past 80 years,” Clemens noted, “but we are now at a point where we have to go through the data-center challenge rather than around it.”
The discussion focused on three interlocking problems: a fragmented regional market structure, chronic transmission bottlenecks, and a regulatory framework that often bars private investors from funding the upgrades the grid urgently needs.
The Scale of New Electricity Demand
The scale of the new load is striking. Roughly 100 “knowledge factories” in the Chicago area were originally slated to draw 38 GW of power; after regulatory review the figure was trimmed to about 30 GW.
By contrast, the region’s historic peak demand was 23.7 GW in July 2011. If the current trajectory continues, the state’s integrated resource adequacy study warns that by 2030 Illinois will lack sufficient generation capacity to meet the added load, triggering a fresh integrated resource planning process.
Who Pays for Grid Expansion?
Addressing the financing gap emerged as a central theme. Under today’s model, utility customers shoulder the cost of grid upgrades through their monthly bills, a structure that spreads the expense of large, fast-growing loads across all ratepayers.
Panelists argued that this approach is inequitable when deep-pocketed data centers join the system quickly and often lack the expertise to absorb the full cost of interconnection.
Proposed remedies include market segmentation that separates residential customers from large industrial users, upfront fees and collateral requirements for new projects, and the use of capacity-payment mechanisms that reward resources able to respond during peak periods.
New Jersey’s Data Center Approach
New Jersey’s recent legislation offers a concrete illustration. The state now requires data centers to post substantial upfront fees and provide letters of credit before the grid commits to serve them.
The legislation also enables distributed energy resources (DERs)—such as heat pumps, electric-vehicle chargers, batteries and rooftop solar—to aggregate into virtual power plants that can supply peak-hour capacity.
Similar capacity-payment and DER-integration policies have been adopted in Illinois and Virginia, signaling a broader shift toward using low-carbon resources to meet growing demand.
The Need for a More Unified Electricity Market
The panel also highlighted the need for a more cohesive national electricity market. The United States presently operates a patchwork of regional markets and transmission operators, a configuration that hampers competition and keeps prices higher than necessary.
Aligning the market would require amending the Energy Policy Act of 2005 to expand FERC’s authority over transmission planning and siting, as well as establishing a national framework for price signals that can attract new wind, solar, storage and flexible gas resources.
However, state officials remain wary of ceding control, and the governance structure of multi-state entities such as PJM—already criticized for being overly influenced by generators—adds another layer of political complexity.
Improving Grid Efficiency
Capacity utilization across the grid hovers at only 50-60 percent, meaning many plants sit idle much of the time.
Experts argued that better utilization could be achieved by directing excess capacity to large, responsive loads like data centers, thereby increasing megawatt-hours sold without raising fixed costs.
Yet price caps imposed by state regulators, intended to protect consumers, often suppress the very price signals needed to incentivize new clean-energy investment.
In the Mid-Atlantic, PJM’s capacity auctions have repeatedly hit the price cap, limiting the market’s ability to attract additional generation and driving up residential bills—about $16 of a recent $107 monthly charge stems from supply-side costs passed through from PJM.
Distributed Energy Resources and Storage
To bridge the short-term gap, utilities are turning to DERs and storage. KMED has approved a virtual power plant program and deployed a Distributed Energy Resource Management System (DERMS) to integrate clean resources and support low- to moderate-income customers.
Community solar projects are also expanding rapidly in Illinois, with roughly 500 installations ranging from 2 MW to 5 MW.
Declining battery costs further bolster the outlook for flexible, low-carbon resources that can smooth demand spikes and improve overall system efficiency.
Transmission Investment Remains Critical
Nevertheless, panelists cautioned that market reforms alone will not resolve the underlying infrastructure constraints.
“The existing system was not built for rapid growth,” said Piser, emphasizing that transmission upgrades remain essential even as the market evolves.
Without coordinated investment in new lines and modernized interconnection processes, the grid will continue to face bottlenecks that limit the integration of renewable generation and storage.
The Path Forward
The consensus was clear: unless policymakers act decisively—whether by expanding FERC’s mandate, revising state rate structures, or enacting legislation that ensures large loads pay their fair share—the United States risks a looming electricity shortage that could curtail both economic growth and climate-decarbonization ambitions.
A sustained crisis, such as a regional blackout, might finally provide the political momentum needed to implement the sweeping reforms that experts deem necessary to keep the nation’s power system reliable, affordable and ready for the next wave of electrified innovation.