Smart Grid Statistics 2026
By Axis Intelligence Research
Co-author: Aidan Jad | Last updated: September 25, 2026 | License: CC BY 4.0
The United States had 128.4 million advanced meters in operation at the end of 2023, 76.8% of all meters, according to FERC’s 2025 Assessment of Demand Response and Advanced Metering. Yet Axis Intelligence Research calculates that only 14.2 customers are on a time-varying rate for every 100 of those meters.
Quick Answer: What Do Smart Grid Statistics Show in 2026?
The hardware layer of the smart grid is largely built; the activation layer is not. The U.S. has 128.4 million advanced meters (76.8% penetration), Great Britain 42 million smart and advanced meters (72%), and India 5.28 crore (52.8 million) smart meters. But Axis Intelligence Research’s Grid Edge Activation Ratio (GEAR™) puts U.S. activation at just 14.2%.
Key Findings
- According to Axis Intelligence Research, the U.S. Grid Edge Activation Ratio (GEAR™) stood at 14.2 dynamic-pricing enrollments per 100 advanced meters in 2023, up from 13.1 in 2022, computed from FERC and EIA-861 data.
- According to Axis Intelligence Research, 3.13 million of Great Britain’s 40.3 million smart meters (7.8%) were running in traditional “dumb” mode at the end of June 2026, based on DESNZ data.
- According to Axis Intelligence Research, India’s RDSS scheme had installed 19.0% of its 19.79 crore sanctioned consumer smart meters by December 31, 2025, based on Ministry of Power data released via PIB.
- The IEA estimates dynamic ratings, topology optimisation and advanced power-flow control could connect up to 330 GW more generation, storage and demand without reinforcement, avoiding around USD 100 billion of network investment (September 2026).
- According to Axis Intelligence Research, North America’s 33 GW of virtual power plants must grow 2.4x to 4.8x to reach the U.S. Department of Energy’s 80–160 GW target for 2030.
How Many Smart Meters Are Installed in the U.S. in 2026?
The most recent federal count is 128.4 million advanced meters at the end of December 2023, out of 167.2 million total meters, a penetration rate of 76.8%. FERC staff reported the figure in December 2025, using EIA Form 861 data; that release is still the latest official national count because EIA’s retail data runs roughly two years behind.
Growth has been steady rather than dramatic. Utilities added approximately 9.1 million advanced meters from 2022 to 2023, a 7.6% annual increase. Over the 16 years since 2007, when FERC counted 6.7 million advanced meters (4.7% penetration), the installed base has multiplied roughly 19 times, per Axis Intelligence Research calculation.
FERC’s definition matters for anyone comparing countries: an “advanced meter” measures and records usage at least hourly and delivers data at least daily. Older automated meter reading (AMR) units, which only transmit one-way billing reads, do not count.
U.S. Advanced Meter Penetration by Year
| Year (Dec) | Advanced meters (millions) | Total meters (millions) | Penetration | Source |
|---|---|---|---|---|
| 2007 | 6.7 | 144.4 | 4.7% | FERC survey |
| 2014 | 58.5 | 144.3 | 40.5% | EIA-861 via FERC |
| 2018 | 86.8 | 154.1 | 56.4% | EIA-861 via FERC |
| 2020 | 103.1 | 159.7 | 64.6% | EIA-861 via FERC |
| 2022 | 119.3 | 165.0 | 72.3% | EIA-861 via FERC |
| 2023 | 128.4 | 167.2 | 76.8% | EIA-861 via FERC |
Smart Meter Penetration by U.S. Region
The national figure hides a 64.7-percentage-point spread between regions. West South Central (Arkansas, Louisiana, Oklahoma, Texas) leads at 90.1%, while New England sits at 25.4%, the only Census Division below 50%.
| Census Division | Residential | Commercial | Industrial | All classes |
|---|---|---|---|---|
| West South Central | 90.5% | 87.9% | 80.0% | 90.1% |
| South Atlantic | 89.0% | 86.0% | 66.5% | 88.6% |
| Pacific | 83.3% | 83.2% | 83.0% | 83.3% |
| East South Central | 83.0% | 78.2% | 78.9% | 82.3% |
| East North Central | 81.7% | 78.1% | 71.2% | 81.3% |
| Mountain | 77.1% | 65.8% | 69.9% | 75.7% |
| West North Central | 67.2% | 60.1% | 72.5% | 66.4% |
| Middle Atlantic | 53.1% | 46.6% | 65.6% | 52.3% |
| New England | 25.4% | 25.4% | 25.5% | 25.4% |
| All regions | 77.3% | 73.3% | 74.5% | 76.8% |
Source: FERC 2025 Assessment, Table 2-2 (EIA-861, 2023 data).
The Mountain division moved fastest in 2023, adding more than 1.6 million advanced meters (+20%), led by PacifiCorp in Utah. Deployment is also still contested: Colorado passed a 2025 law requiring utilities to notify residential customers 90, 60 and 30 days before an AMI installation and to explain their right to refuse one.
Aidan Jad’s read: New England’s 25.4% is not a technology gap, it’s a regulatory sequencing story. The region’s utilities ran AMR fleets that still read bills fine, so the business case had to be rebuilt around distribution-system value rather than meter-reading savings. Rhode Island’s 2025 approval shows the pattern: a $15.3 million capital recovery cap and meter data management system costs excluded from rate base. That is how you get a slow, audited rollout rather than a fast one.
Are Smart Meters Actually Being Used? The Grid Edge Activation Ratio (GEAR™)
A smart meter on the wall is capacity. A customer on a time-varying rate, or enrolled in a demand response program, is the grid actually using it. Nobody publishes that conversion rate directly, so Axis Intelligence Research built one.
Grid Edge Activation Ratio (GEAR™) = customers enrolled in retail dynamic pricing ÷ advanced meters in operation × 100
Dynamic pricing covers time-of-use, real-time pricing, variable peak pricing, critical peak pricing and peak-time rebates, as defined by EIA Form 861.
| Input / output | 2022 | 2023 | Source |
|---|---|---|---|
| Customers in retail dynamic pricing | 15,596,979 | 18,240,088 | FERC Table 5-2 (EIA-861) |
| Advanced meters in operation | 119.3 million | 128.4 million | FERC Table 2-1 (EIA-861) |
| GEAR™ (per 100 meters) | 13.1 | 14.2 | Axis Intelligence Research |
| Companion: retail DR enrollment per 100 meters | — | 8.2 | Axis (10,567,254 ÷ 128.4M) |
Formula check, 2023: 18,240,088 ÷ 128,400,000 = 0.1421 → 14.2 per 100 meters.
How to read it: a GEAR™ of 100 would mean every advanced meter feeds a price signal to a customer who can respond to it. At 14.2, roughly 86 of every 100 U.S. smart meters still bill like the meters they replaced: a flat rate, read automatically. FERC’s own staff reached the same conclusion in plain words, noting that roughly 11% of all electric customers are enrolled in dynamic pricing against 76.8% advanced meter penetration, and that the lack of meters “may no longer be a primary barrier.”
What moved in 2023: enrollment in dynamic pricing rose by 2.6 million customers (+16.9%), roughly double the 7.6% growth in meters, which is why GEAR™ rose. Most of the gain came from one utility: Consumers Energy in Michigan added 1.5 million customers. Take that out and the ratio barely moved.
What would push GEAR™ up: utility-led enrollment drives like Consumers Energy’s in 2023, new time-of-use offers such as the residential rate Minnesota regulators approved for Xcel in May 2025, bring-your-own-device battery programs such as Arizona Public Service’s pilot paying $110/kW-year, and state VPP mandates. What would hold it down: opt-in enrollment, meter opt-out laws, and the Pacific division’s dynamic pricing count falling 2.6% in 2023 despite its 83.3% penetration.
Aidan Jad’s read: GEAR™ separates two questions that utility filings love to merge. “How much AMI did we deploy?” is a capex question with a clean answer. “How many kilowatts moved off-peak because of it?” is an operations question most rate cases never ask. The 2023 jump came from a single Michigan utility, which tells you the lever is rate design, not hardware.
How Much Demand Response Is Available on the U.S. Grid?
Demand response in the seven U.S. wholesale markets reached 33,272 MW in 2024, up 217 MW (0.7%), and could cover about 6.5% of the combined non-coincident peak across RTOs and ISOs, which was roughly 515 GW, according to FERC.
Wholesale Demand Response by RTO/ISO (2024)
| RTO / ISO | DR resources 2024 (MW) | % of peak | Change vs 2023 | Source |
|---|---|---|---|---|
| MISO | 12,954 | 10.6% | +2.3% | FERC Table 3-3 |
| PJM | 8,526 | 5.7% | −11.8% | FERC Table 3-3 |
| CAISO | 4,373 | 9.0% | +5.3% | FERC Table 3-3 |
| ERCOT | 4,099 | 4.8% | +13.5% | FERC Table 3-3 |
| NYISO | 1,921 | 6.1% | +12.4% | FERC Table 3-3 |
| SPP | 968 | 1.8% | +22.1% | FERC Table 3-3 |
| ISO-NE | 431 | 1.7% | −5.5% | FERC Table 3-3 |
| Total | 33,272 | 6.5% | +0.7% | FERC |
On the retail side, utilities reported 30,542 MW of potential peak demand savings in 2023, up just 0.3%, with 10.6 million customers enrolled in incentive-based programs. Industrial customers supply the largest share of that retail potential (45.3%), ahead of residential (31.7%) and commercial (23.0%). Axis Intelligence Research does not add the retail and wholesale totals, because FERC compiles them from different datasets and some retail programs bid into wholesale markets.
Does Demand Response Actually Deliver in a Heat Wave?
It did in June 2025. PJM deployed demand response that reduced system peaks by more than 4,000 MW during June 23–25, when demand reached about 162,000 MW, its third-highest peak on record. On August 11, 2025, demand response and voltage reduction after a Baltimore substation loss cut a potential 1,200 MW load shed to a 20 MW loss lasting 28 minutes, per FERC’s account of PJM’s report.
The market has also had to police itself. FERC settled with aggregator Voltus in January 2025, which agreed to disgorge $7,080,543 and pay a $10,919,457 civil penalty over MISO participation. MISO has since tightened meter-data verification requirements for demand resources.
Aidan Jad’s read: PJM’s 11.8% drop in registered demand response in the same year it leaned on demand response to ride a near-record peak is the tension to watch. Registration numbers follow capacity-market rules; the heat-wave numbers follow physics. From the 2027/2028 delivery year PJM moves demand resources to a 24-hour annual availability window, which will likely cut the registered MW again while raising what each MW is worth.
How Big Are Virtual Power Plants in 2026?
Virtual power plants in North America have reached 33 GW, according to the U.S. Department of Energy’s VPP Liftoff update. The DOE says deploying 80–160 GW of VPPs, enough to serve 10–20% of peak load, by 2030 could support rapid load growth while reducing grid costs. Axis Intelligence Research calculates that means a 2.4x to 4.8x scale-up from today’s base in roughly four years.
State programs are where that capacity is being written into law. Virginia directed Dominion Energy to run a VPP pilot of up to 450 MW of distributed energy resource aggregations, and Dominion filed its program with the Virginia State Corporation Commission on December 1, 2025. California’s Demand Side Grid Support program now lets aggregators field load-flexibility VPPs from 200 kW upward. Texas went the other direction for large loads: a 2025 law lets ERCOT curtail new customers of 75 MW or more, such as data centers, during firm load-shed events.
Aidan Jad’s read: The 33 GW figure counts enrolled flexibility, not dispatched megawatt-hours. The engineering questions a planner should ask a VPP operator are the same ones asked of a peaker: guaranteed duration, response time, and performance when called in the fourth consecutive hot day. The GEAR™ gap above is also the VPP gap: a VPP is only as large as the number of meters actually tied to a price or dispatch signal.
What Share of Smart Meters Work in Great Britain?
Great Britain had 42 million smart and advanced meters at the end of June 2026, 72% of all meters in homes and small businesses, according to the DESNZ quarterly statistics. Of roughly 40 million smart meters, 92% were operating in smart mode, meaning they communicate remotely with the supplier.
| GB metric (end June 2026) | Value | Source |
|---|---|---|
| Smart meters in smart mode | 37,185,000 | DESNZ Table 1 |
| Smart meters in traditional mode | 3,133,000 | DESNZ Table 1 |
| Advanced meters | 1,239,000 | DESNZ Table 1 |
| Non-smart meters | 15,941,000 | DESNZ Table 1 |
| All meters | 57,498,000 | DESNZ Table 1 |
| Homes with a smart electricity meter | 75% | DESNZ |
| Share of traditional-mode smart meters | 7.8% | Axis Intelligence Research |
The new data point in this release is replacements. Large suppliers installed 1,095,000 meters in Q2 2026, but only 525,000 were new installations; 570,000 replaced existing smart meters. In homes, replacements rose from 14% of installations in Q1 2022 to 53% in Q2 2026. Part of the programme’s labour is now spent swapping first-generation smart meters, either at end of life or to keep them compatible with current communications.
Axis Intelligence Research estimates that at Q2 2026’s pace of 525,000 new installations per quarter, the 15.9 million remaining non-smart meters would take about 30 quarters, or roughly 7.6 years, to replace. This is a pace illustration, not a forecast: new installations also include new metering points, and installation rates shift with policy.
How Is India’s Smart Meter Rollout Progressing?
India’s Revamped Distribution Sector Scheme (RDSS) has sanctioned smart metering for 19.79 crore consumers, 52.53 lakh distribution transformers and 2.05 lakh feeders across 45 distribution utilities in 28 states and union territories, according to a Ministry of Power reply released by PIB on February 2, 2026. By December 31, 2025, 3.90 crore meters had been installed under RDSS, and 5.28 crore across all schemes.
| RDSS component (Dec 31, 2025) | Sanctioned | Installed | Installed share | Source |
|---|---|---|---|---|
| Consumer meters | 19,79,30,130 | 3,76,56,989 | 19.0% | PIB; share: Axis |
| Distribution transformer meters | 52,52,692 | 12,56,448 | 23.9% | PIB; share: Axis |
| Feeder meters | 2,05,475 | 1,58,479 | 77.1% | PIB; share: Axis |
| All RDSS meters | 20,33,88,297 | 3,90,71,916 | 19.2% | PIB; share: Axis |
Maharashtra led installations with 83.7 lakh meters, followed by Uttar Pradesh (62.5 lakh) and Assam (47.3 lakh). Tamil Nadu, with 3 crore consumer meters sanctioned, had installed none at consumer level.
The activation question shows up in India too, in a different form. In a REC and PFC feedback survey of 1,24,590 consumers who had downloaded a utility app, 54,321 knew about the real-time consumption feature. Axis Intelligence Research calculates that is 43.6%. Aggregate technical and commercial losses fell from 21.91% in FY2021 to 15.04% in FY2025, the Ministry says, crediting smart metering among other reforms.
Aidan Jad’s read: India’s rollout is prepaid-first, so its first return is revenue collection, not load flexibility. Feeder meters are 77.1% installed because DISCOMs need energy accounting before anything else. Consumer meters trail at 19.0%. Once consumer coverage climbs, India will face the same GEAR™ question as the U.S., just starting from a tariff structure with far fewer time-of-day signals.
How Advanced Is Smart Meter Rollout in the European Union?
Smart meter deployment has reached 80% in half of EU Member States, while in seven it remains below 20% or data was not provided, according to ACER’s 2025 retail country sheets. Fixed-price or regulated contracts still dominate household electricity in 15 Member States, which ACER says limits exposure to real-time price signals. In 21 Member States prosumers make up between 1% and 10% of households, with the Netherlands (30%) and Belgium (22%) highest.
The EU pattern mirrors the U.S. one: meters first, price signals later. ACER does not publish a single EU-wide dynamic-contract share, so Axis Intelligence Research does not compute a European GEAR™ reading from these figures.
How Much Grid Capacity Can Digital Technology Unlock?
The IEA published Modernising Grids in the Age of Electricity on September 21, 2026. Its central estimate: dynamic ratings, topology optimisation and advanced power-flow control could allow up to 330 GW of additional generation, storage and demand to connect to existing networks without reinforcement. Connecting the same volume through network expansion would require around USD 100 billion of investment. Axis Intelligence Research calculates that is about USD 303 million of avoided expansion per GW.
| Smart grid metric | Value | Year | Source |
|---|---|---|---|
| Capacity unlockable by three digital/GET tools | up to 330 GW | 2026 | IEA |
| Expansion cost avoided | ~USD 100 billion | 2026 | IEA |
| Avoided cost per GW | ~USD 303 million | 2026 | Axis Intelligence Research |
| Grid congestion cost, United States | USD 12 billion | 2024 | IEA |
| Grid congestion cost, European Union | EUR 4.3 billion | 2024 | IEA |
| Advanced-stage renewables awaiting connection | at least 1,700 GW | 2025 | IEA |
| Utility-scale batteries awaiting connection | 600 GW | 2025 | IEA |
| Avoided congestion from dynamic ratings (U.S.) | USD 64 million / year | 2026 | IEA |
| Added transfer capacity from power-flow control (GB) | more than 2 GW | 2026 | IEA |
| Operators using AI widely for maintenance | 70% | 2026 | IEA survey |
| Operators using AI in real-time operations | 23% | 2026 | IEA survey |
The barriers the IEA found are organisational. Among surveyed network operators, 64% cited skills and organisational readiness, 60% data availability and quality, 60% trust issues and 56% regulatory frameworks. The grid workforce is also ageing: workers aged 55 and over rose by nearly 50% between 2015 and 2024.
Readers following transmission-level capacity, queue backlogs and transformer lead times will find the full picture in our power grid statistics, including the Grid Friction Multiple. This page stays on the digital and distribution layer.
Aidan Jad’s read: The 70% versus 23% AI split is the most honest number in the IEA report. Maintenance models recommend; a human decides. Real-time control acts, and an operator has to explain every action to a regulator after an event. Until validation and certification standards exist, AI on the grid will keep growing in the asset-management back office faster than in the control room.
Methodology
Collection. Axis Intelligence Research fetched and read each source on September 25, 2026: FERC’s 2025 Assessment of Demand Response and Advanced Metering (December 2025, based on EIA Form 861 2023 retail data and RTO/ISO 2024 wholesale data); DESNZ Smart meters in Great Britain, quarterly update June 2026 (August 27, 2026); the Ministry of Power reply released by PIB on February 2, 2026 (data as of December 31, 2025); ACER’s 2025 retail country sheets announcement (July 18, 2025); the IEA’s Modernising Grids in the Age of Electricity (September 21, 2026); and the DOE VPP Liftoff page (2025 update).
Axis calculations (all in the CSV method_note column):
- GEAR™ = dynamic-pricing enrollment ÷ advanced meters × 100. 2023: 18,240,088 ÷ 128,400,000 = 14.2. 2022: 15,596,979 ÷ 119,300,000 = 13.1.
- Retail DR enrollment per 100 meters: 10,567,254 ÷ 128,400,000 × 100 = 8.2.
- GB traditional-mode share: 3,133,000 ÷ (37,185,000 + 3,133,000) = 7.8%.
- GB remaining-meter pace: 15,941,000 ÷ 525,000 = 30.4 quarters (estimate).
- India installed shares: installed ÷ sanctioned per PIB table.
- India app awareness: 54,321 ÷ 1,24,590 = 43.6%.
- VPP scale-up: 80 ÷ 33 = 2.4; 160 ÷ 33 = 4.8.
- IEA avoided cost per GW: USD 100 billion ÷ 330 GW = ~USD 303 million.
- AMI growth since 2007: 128.4 ÷ 6.7 = 19.2x.
Every figure was computed twice (floating point and exact rational arithmetic) with identical results.
Scope. GEAR™ compares customer enrollments with meter counts. Some commercial and industrial customers have more than one meter, and EIA reports enrollments by utility at state level, so the ratio is an approximation of activation, not a customer-level measurement. It captures price-based activation only; direct load control counted under demand response is shown separately. U.S. retail data runs through 2023, the latest year in the federal series. The GB figures combine large suppliers (June 2026) and small suppliers (December 2025), as DESNZ publishes them. India figures are installations, not commissioned or billing meters. VPP capacity is DOE’s North America estimate, while the 80–160 GW target is U.S.-only.
About This Dataset
Title: Smart Grid Statistics 2026: Smart Meters, Demand Response, Virtual Power Plants and the Grid Edge Activation Ratio
File: smart-grid-statistics.csv — one observation per row, with source organisation, document, URL, retrieval date, primary flag and Axis calculation notes on every row.
Coverage: United States (national, 9 Census Divisions, 7 RTO/ISOs), Great Britain, India (national and leading states), European Union, World; observations 2007–2026, targets to 2030.
Creator and publisher: Axis Intelligence Research · License: CC BY 4.0
Cite as: Axis Intelligence Research, Smart Grid Statistics 2026, 2026, axis-intelligence.com/smart-grid-statistics/
Cite This Research
APA: Axis Intelligence Research. (2026, September 25). Smart grid statistics 2026: Smart meters, demand response, virtual power plants and the Grid Edge Activation Ratio. Axis Intelligence. https://axis-intelligence.com/smart-grid-statistics/
MLA: Axis Intelligence Research. “Smart Grid Statistics 2026: Smart Meters, Demand Response, Virtual Power Plants and the Grid Edge Activation Ratio.” Axis Intelligence, 25 Sept. 2026, axis-intelligence.com/smart-grid-statistics/.
Chicago: Axis Intelligence Research. “Smart Grid Statistics 2026: Smart Meters, Demand Response, Virtual Power Plants and the Grid Edge Activation Ratio.” Axis Intelligence, September 25, 2026. https://axis-intelligence.com/smart-grid-statistics/.
Smart Grid FAQ: What Utilities, Regulators and Aggregators Are Asking
If 77% of U.S. meters are smart, why are so few customers on time-of-use rates?
Meters were justified mostly on meter-reading and outage savings, while rate design stayed opt-in. FERC notes that roughly 11% of U.S. electric customers are on dynamic pricing against 76.8% advanced meter penetration. Axis Intelligence Research’s GEAR™ puts the ratio at 14.2 enrollments per 100 meters (2023).
Which U.S. region has the fewest smart meters?
New England, at 25.4% advanced meter penetration in 2023, the only Census Division below 50%, according to FERC. West South Central leads at 90.1%. The 64.7-point gap is the widest regional spread in the federal data.
How many megawatts of demand response can U.S. grid operators call on?
33,272 MW across the seven RTOs and ISOs in 2024, about 6.5% of their combined peak, per FERC. MISO holds the most (12,954 MW); PJM registered 11.8% less than in 2023. Utility retail programs report a further 30,542 MW of potential peak savings (2023), not additive to the wholesale figure.
What counts as a “working” smart meter in Great Britain?
A smart meter in smart mode communicates remotely with the supplier. At the end of June 2026, 92% of Great Britain’s roughly 40 million smart meters were in smart mode, per DESNZ. Axis Intelligence Research counts the other 3.13 million, 7.8%, as operating in traditional mode.
Why are half of new smart meter installs in Britain replacements?
Suppliers are swapping first-generation smart meters at end of life or to keep communications compatible. Replacements rose from 14% of domestic installations in Q1 2022 to 53% in Q2 2026, according to DESNZ, which published replacement data for the first time in August 2026.
Is India on track to finish its RDSS smart meter rollout?
Not on the original timeline. By December 31, 2025, 19.0% of 19.79 crore sanctioned consumer meters were installed under RDSS, per Axis Intelligence Research analysis of Ministry of Power data. Feeder metering was much further along at 77.1%.
How large must U.S. virtual power plants become by 2030?
The DOE targets 80–160 GW, enough to serve 10–20% of peak load, against 33 GW across North America today. Axis Intelligence Research calculates that requires a 2.4x to 4.8x increase.
Can digital grid tools replace building new power lines?
Partly, and faster. The IEA estimates dynamic ratings, topology optimisation and power-flow control could connect up to 330 GW without reinforcement, worth around USD 100 billion of avoided expansion. The IEA says these tools complement, not replace, grid expansion.
What is the Grid Edge Activation Ratio (GEAR™)?
GEAR™ is an Axis Intelligence Research metric: customers on dynamic electricity pricing per 100 advanced meters in operation. It measures how much installed smart metering is actually tied to a price signal. The U.S. reading was 14.2 in 2023, up from 13.1 in 2022.
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