Exelon CEO Warns of 2027 Blackouts as Utility Underinvestment Debate Returns
Exelon's Calvin Butler is pushing states to let utilities build generation, backed by research showing only 1.2% real annual rate base growth over two decades.
Utility Dive's analysis published on Tuesday (2026-07-22) cut to the heart of a debate that Exelon's Calvin Butler has been forcing into public view: distributed resources and new generation only deliver full value when connected to a well-financed, well-operated network. "A distributed resource that isn't part of a well-financed, well-operated network is half an asset, and a brittle one," the piece stated. That framing matters for anyone trying to price capacity risk in PJM and adjacent markets.5
Butler, chief executive of Exelon, the largest utility in the United States, has been warning that blackouts are coming in 2027 unless states allow utilities to build new power plants. OilPrice.com reported his position on Sunday (2026-07-13). Opponents counter that shifting construction risk from developers onto ratepayers is the wrong medicine for a problem utilities helped create.3
The underinvestment case rests on two decades of data. Research covering utility capital allocation from 2004 to 2024 found that after adjusting for inflation, the industry added only 1.2% per year to the real rate base over that span, according to the OilPrice.com report published on Sunday (2026-07-13). The same research noted that before the COVID period, the electric industry was estimated to be underinvesting by close to 50%.3
Yet the case has gaps. Utilities expanded their nominal rate bases substantially over that same 2004-2024 window. The inflation adjustment is doing significant work in producing that 1.2% figure, and critics argue that even flat real investment was inflated relative to actual system need. The OilPrice.com analysis noted that utility managers tend to deploy excess capital only when returns exceed their cost of capital — a threshold that functions as either discipline or a floor depending on how regulators set allowed returns.3
PJM, the grid operator covering the mid-Atlantic and parts of the Midwest, raised capacity rates substantially in its most recent auction, forcing utilities in the footprint to rethink both generation portfolios and demand management strategies. A Utility Dive piece published on Sunday (2026-07-06) described how at least one utility reduced system demand at peak periods through existing gas generation and demand response, generating millions in savings over the past decade. That operational flexibility exists in some systems. It does not exist everywhere.2
Where flexibility is absent, the capacity gap Butler is pointing to becomes real in ways rate cases alone cannot resolve. The grid reliability picture is complicated further by extreme weather exposure. Sub-kilometer weather forecasting models — both physics-based and AI-native — are now being used by utility executives trying to manage wildfire and storm risk, according to a Power Magazine analysis published on Monday (2026-06-08). The divide between those two forecasting approaches carries legal and regulatory implications: a wrong call made with an inferior model, in a wildfire season that turns lethal, is an operational failure and a liability event.1
Offshore wind adds another layer of integration complexity. EnergyVoice's analysis published on Tuesday (2026-07-22) noted that many of the biggest risks in offshore development now sit between work packages rather than within them — an integration problem, not purely an engineering one. Owner's engineers are being asked to manage interfaces that project structures were not originally designed to handle. Transmission interconnection delays or cost overruns in offshore integration slow the new supply that regulators and executives are counting on.4
What Butler wants — state approval to build utility-owned generation — would shift construction and cost risk from merchant developers onto captive ratepayers. That trade-off is not new. It has been litigated in state capitals for decades. But demand growth projections, driven in part by data center load and electrification, are running well above what utilities modeled five years ago, while supply additions have lagged. The 2027 blackout timeline is aggressive. The direction of the capacity math is not seriously disputed.3
The Utility Dive argument published on Tuesday (2026-07-22) is harder to dismiss on those terms: if real annual additions to the rate base ran at only 1.2% across twenty years, the nominal investment figures overstated the margin available when demand accelerated. The next stress test arrives when peak summer demand meets whatever capacity cleared in the most recent PJM auction — and Butler's public warning is partly designed to ensure regulators feel that pressure before the result lands.5,3