U.S. Smart Meter Coverage Hits 72% but Data Gaps Constrain Grid Flexibility
U.S. advanced metering penetration surpassed 72% by 2022, but a $6 billion PJM build-out has yielded little usable demand-response data.
A Utility Dive analysis published Sunday (2026-07-27) found that U.S. advanced metering infrastructure penetration exceeded 72% of the nation's meter base by 2022, up from below 5% in 2008. The build-out transformed utility billing economics but has so far delivered less actionable grid intelligence than the hardware theoretically enables.4
The gap between meter count and grid capability sits at the center of the U.S. power market investment debate. Smart meters are the physical prerequisite for demand response, virtual power plants, and real-time load management — tools grid planners are counting on as data center growth pressures regional systems. Where meters are installed but data does not flow, those tools remain unavailable.4,1
The original build was federally driven. Between 2009 and 2011, penetration tripled from 12.8% to 38.1%, largely on the back of American Recovery and Reinvestment Act incentives, Utility Dive reported. That pace slowed sharply once the program wound down; climbing from 38% to 72% took another decade of piecemeal utility investment.4
Coverage is uneven. Texas and California both report residential and commercial penetration above 80%, while parts of New England remain in the low 30% range, according to Utility Dive. The outlet noted that AMI deployments have settled into distinct tiers: early deployers at or above 80%, a middle cohort still closing first-generation rollouts, and a third group that has yet to achieve initial scale.4
Utilities that moved first face a specific cost problem. Hardware installed during the federal incentive window is now the oldest in the field and, in many cases, least capable of supporting the two-way data flows that second-generation devices are designed to provide. They are first in line for replacement.4
The PJM situation shows what high penetration without data-sharing yields. Utilities across PJM Interconnection, the largest U.S. power market, spent nearly $6 billion to install roughly 12 million smart meters at homes and businesses, Canary Media reported on June 4, 2026. Those meters are not sharing data with grid operators in forms that enable meaningful demand flexibility, the outlet found.1
Independent analysts said virtual power plants and demand-response programs could help absorb peak load pressure, Canary Media reported. Both depend on continuous, interoperable data streams from installed meters. Where utilities have not established sharing protocols, the hardware investment produces billing automation rather than grid intelligence.1
Mordor Intelligence, publishing on June 10, 2026, projected the global smart electricity meter market reaching $23.46 billion by 2031, with single-phase residential units accounting for 63.25% of revenue. The firm forecast unit volumes growing to 269.90 million by the same year at a compound annual growth rate of 7.62%.3,2
The second-generation rollout will not replicate the speed of the first. The 2009-2011 sprint ran on a single federal program with a fixed timeline. AMI 2.0 depends on utility capital planning cycles, state rate cases, and regulatory determinations of whether upgraded metering qualifies as a recoverable cost — a slower process running across dozens of separate jurisdictions.4,1
New England presents the sharpest test. With penetration stuck in the low 30s across parts of the region, utilities there carry both the largest coverage gap and the weakest cost-recovery precedent for AMI investment. How state commissions respond to rate filings for upgraded infrastructure is the most immediate indicator of whether the demand-response potential embedded in the national meter network moves toward deployment or remains stranded inside hardware built for a simpler grid.4,1