"Distributed energy is a future thing." It already runs more daytime power than US nuclear.
The most common mistake in US distributed-energy reporting is treating it as a 2030s phenomenon. EIA tracked small-scale solar PV at roughly 80 GW nameplate by Q1 2026, which already exceeds total US installed nuclear capacity (about 95 GW) and is growing roughly 20% per year. Behind-the-meter battery storage roughly doubled between 2023 and 2025. The technology has crossed every meaningful adoption threshold; only the market rules and the consumer awareness are lagging.
The reason it does not feel that way is that distributed energy is invisible by definition. Utility-scale solar shows up as a single visible project; rooftop solar shows up as 4 million separate homes. A 12 kW Tesla Powerwall battery on a residential meter does not announce itself; a 200 MW Tesla Megapack project gets a press release. The aggregate is far larger than the sum of headlines suggests.
What changes from 2026 onward is the market access. FERC Order 2222, in force since 2020 but only now being implemented by individual ISOs, requires every FERC-jurisdictional grid operator to let aggregated DERs bid into wholesale energy, capacity and ancillary-service markets. ISO New England goes live on 1 November 2026, PJM on 1 February 2028, MISO on 1 June 2029, SPP on Q2 2030. CAISO and NYISO already operate older DER programs that meet or exceed the rule. The customer who installs a battery in 2026 will be paid wholesale-market prices by the end of the decade, in addition to net-metering or net-billing credits at the retail level.
Read the next sections with that in mind: DER is not a future; it is a current grid resource that is finally being priced as one.
Five distributed-energy resource categories you can install today.
A DER is any small-scale generator, storage device or controllable load located on the distribution grid or behind a customer meter. The five categories below cover virtually every residential and small-commercial use case in 2026.
Rooftop solar PV
Typical residential install: 6 to 12 kW, 16 to 32 panels, $2.50 to $3.50/W installed before incentives. 80+ GW already on US homes and small businesses. Federal Residential Clean Energy Credit 30% through 2032.
Home batteries
Tesla Powerwall (13.5 kWh), Enphase IQ Battery 5P (5 kWh), Franklin aPower 2 (15 kWh), SunPower SunVault, FranklinWH, EG4. $900 to $1,400/kWh installed. 30% IRS credit if at least 3 kWh capacity. Doubled in installed base 2023 to 2025.
EV chargers (managed)
Level 2 home charger (7 to 11 kW) with utility load-management or vehicle-to-grid (V2G) capability. Examples: Wallbox Pulsar Plus, Emporia, ChargePoint Home Flex, Tesla Wall Connector. Many utilities pay $50 to $300/year to enroll in managed-charging programs.
Smart thermostats and water heaters
ecobee, Nest, Honeywell connected thermostats; Rheem and AO Smith CTA-2045 grid-connected water heaters. The cheapest controllable DER per kW reduced. Utility BYOT (Bring Your Own Thermostat) programs pay $25 to $150/year per device for summer event participation.
Microgrids
Self-contained generation + storage + control system that can island from the grid during an outage. Residential microgrids (Span + Powerwall + solar), commercial campuses, hospitals, schools, military bases. Most common where outage risk is high (CA wildfire zones, FL hurricane corridor, PR grid-resilience program).
Combined heat and power (CHP)
Small-scale natural-gas or biogas generators that produce electricity and useful heat. Common at hospitals, hotels, university campuses, large industrial sites. The original DER under PURPA 1978. Counted as DER for FERC Order 2222 if sized below the ISO threshold (typically under 20 MW).
The detail that matters most for the household. A solar panel without a battery exports surplus to the grid (compensated at NEM, NEM 2.0, NEM 3.0 or VDER rates depending on your state). A battery without solar shifts grid imports from peak to off-peak hours. Solar + battery together capture both arbitrage values and most of the wholesale-market revenue that Order 2222 will eventually unlock. After California cut export rates by ~75% in NEM 3.0, the residential install mix shifted from solar-only to solar + battery in less than 12 months.
DER type, residential size, wholesale revenue, state support.
What each technology can earn, both at the retail level (net metering, net billing, VDER, utility program) and at the wholesale level (Order 2222 aggregation), in 2026.
| DER type | Typical residential size | Order 2222 wholesale potential | Notable state support |
|---|---|---|---|
| Rooftop solar PV | 6 to 12 kW | Energy market via aggregator, marginal in residential size | NY VDER, MA SMART, IL Adjustable Block, NJ TREC, CA NBT (low export) |
| Home battery (LFP / NMC) | 5 to 30 kWh | High: capacity + energy arbitrage + ancillary services | CA SGIP (low-income + equity), MA ConnectedSolutions, TX EnergyShare |
| Managed EV charger | 7 to 11 kW (40 to 80 A) | Demand response, eventually V2G energy market | CA Demand Side Grid Support, NY EV-managed-charging, ConEd SmartCharge |
| Smart thermostat (BYOT) | 3 to 8 kW connected load | Demand response only (no export) | Most utilities run their own program: ConEd Smart Usage Rewards, FPL OnCall, Duke, Xcel SaverSwitch |
| CTA-2045 water heater | 4 to 5 kW heating element | Demand response, eventually frequency regulation | BPA program in PNW; emerging in NY, MA |
| Residential microgrid | 10 to 30 kW solar + 20 to 60 kWh battery | High during grid-connected mode; islands during outage | CA SGIP Equity Resiliency, PR Energy Resilience Loan, FL Self-Generation rules |
! The two cliffs to plan around
First, the 30% Residential Clean Energy Credit drops to 26% on 1 January 2033, 22% in 2034, then expires. Second, every state with generous net metering (PR Act 17, NV NEM, AZ APS legacy, FL NEM) is in some stage of revisiting. CA already cut export compensation by ~75% in NEM 3.0 / NBT. Time-to-act windows are real; do not assume current state-program economics hold for the full 25-year solar warranty period.
When your DER can actually earn wholesale revenue, by ISO.
FERC Order 2222 was issued in September 2020. Implementation is staggered by ISO because each had to file a compliance plan and FERC had to approve it. The dates below are the live or expected go-lives as of May 2026. CAISO and NYISO had functional DER programs before Order 2222 and are continuing to refine them.
A Live or already in place
CAISO: Distributed Energy Resource Provider (DERP) and Demand Response programs since 2014, refined under Order 2222. NYISO: DER market model live since 2022, full Order 2222 compliance filing approved.
B Launch within 12 months
ISO New England goes live on 1 November 2026, the first under the FERC Order 2222 compliance schedule. Initial market access in energy + reserves; capacity-market integration phased in 2027 to 2028.
C 2028 to 2030 launches
PJM: 1 February 2028. MISO: 1 June 2029. SPP: Q2 2030. Each is filing implementation amendments through 2026 to 2027. Aggregator registration windows open ~12 months before each go-live.
D Outside FERC: ERCOT
ERCOT is state-jurisdictional (PUCT) and not bound by Order 2222. It runs its own Aggregated DER (ADER) pilot since 2022, with permanent rules under PUCT consideration. RTC+B (December 2025) prices battery storage in real time, regardless of size; small batteries can already earn ancillary-service revenue.
The takeaway: a battery installed in 2026 in ISO-NE territory (CT, MA, ME, NH, RI, VT) can plausibly start earning wholesale revenue through an aggregator by year-end. The same battery installed in PJM (IL ComEd, OH, PA, NJ, MD, DC, VA, DE, WV, e-KY, NC, IN, MI) waits until early 2028. The hardware and the demand-response programs work today; what changes is the access to the wholesale price stack.
The structural changes between 2023 and 2026 that matter most.
Four shifts in three years remade the residential DER calculation. The hardware costs fell, the federal credit was locked at 30% through 2032, California cut export rates by 75% and battery installations doubled. Each is now baked into the 2026 install economics.
Behind-the-meter solar PV
Already exceeds total US nuclear capacity by nameplate (~95 GW). EIA Monthly Energy Review, Q1 2026.
Battery storage 2023 to 2025
Utility-scale + behind-the-meter combined roughly doubled. Behind-the-meter grew fastest in CA (post-NEM 3.0), TX and PR.
IRS credit, locked to 2032
Residential Clean Energy Credit, restored to 30% by IRA 2022. No cap. Carries forward.
CA NEM 3.0 export cut
Net Billing Tariff (April 2023) replaced full retail credit with avoided-cost compensation. Install mix shifted to solar + battery within 12 months.
Three implications for the 2026 household decision
- A Solar without battery is a state-dependent bet. In a state with strong net metering (NJ, NY VDER, MA SMART, IL Adjustable Block), solar-only still pencils. In CA, FL or AZ with NEM 3.0-style export rates, you need a battery to capture most of the value through self-consumption.
- B Battery economics depend on rate design. A flat-rate utility tariff gives a battery little to arbitrage. A time-of-use rate (CA, NY, MA, parts of TX and FL) plus a critical-peak rate gives a battery real revenue. Check the available tariffs on your incumbent's website before sizing.
- C Aggregator selection now matters. Order 2222 will let your battery, thermostat or EV charger earn wholesale dollars only through an aggregator. Sunrun, OhmConnect, Voltus, CPower, Octopus, Span, Tesla VPP, Enphase VPP and others are recruiting in different states. The aggregator economics differ; read the contract before signing.
Four structural reasons distributed energy is bigger than the headlines suggest.
DER policy makes headlines when a state cuts net metering or when FERC issues a new order. The underlying installed base grows roughly 15 to 20% a year without anyone noticing. Four structural drivers explain why the gap between perception and reality keeps widening.
Cost curves are still falling
NREL Annual Technology Baseline shows residential solar installed costs falling roughly 3 to 5% per year on a multi-year average, despite supply-chain disruptions in 2022 to 2023. Battery cell prices fell harder: lithium-iron-phosphate (LFP) cell prices dropped roughly 30% in 2024 to 2025, partly offset by integration and installation cost. The hardware bill of materials no longer constrains adoption; permitting and interconnection do.
Interconnection is the new bottleneck
In high-penetration zones (parts of HI, CA, MA, NJ, VT, large stretches of TX residential clusters) the distribution feeder is at or past hosting-capacity limits. Interconnection studies take 3 to 12 months, sometimes longer. The IEEE 1547 and IEEE 2030.5 standards plus state-level interconnection reforms (NY Standardized Interconnection Requirements, CA Rule 21) are slowly easing the queue, but interconnection delay is now a bigger headwind than hardware cost.
Order 2222 unlocks a stacked revenue model
A battery in PJM territory after February 2028 can earn capacity revenue (via aggregator clearing in BRA), energy revenue (real-time arbitrage), ancillary-service revenue (regulation, spinning reserve), and retail-side revenue (utility demand-response programs and net-metering credits). These stack. Single-revenue payback models (the typical financing pitch) systematically understate the long-run economics.
Resilience value is no longer hypothetical
After Hurricane Helene (Sep 2024), Hurricane Beryl (Jul 2024) and the February 2021 Texas freeze, the dollar value of riding through an outage is concrete. Insurance discounts (in some states), priority restoration premia and the avoided spoilage / lost wages cost are now itemised in residential battery sales pitches. The Puerto Rico Energy Resilience Loan formalised this calculus at the federal level; 4 to 7-day battery autonomy is the design target.
The combined effect: distributed energy is no longer a hobbyist or environmentalist purchase. It is a capacity asset on the grid that the wholesale market will start paying for from 2026 onward, and a resilience asset on your home that already has measurable insurance value. The narrative caught up to the data, slowly.
Six concrete steps for a 2026 DER decision.
Check your state's export rate first
Net metering 1.0 (full retail), NEM 2.0 (retail with small fees), VDER (NY: per-component), NBT (CA: avoided cost), Adjustable Block (IL), SMART (MA). The export rate sets whether solar-only or solar + battery makes sense.
Confirm the federal 30% credit
IRS Residential Clean Energy Credit covers 30% of installed cost on qualifying solar, battery (3 kWh+), geothermal, small wind. Locked at 30% through 2032; drops in 2033. Form 5695. No cap.
Get three independent quotes
Solar + battery quotes vary by 30 to 50% on the same hardware. Use EnergySage, Solar Reviews, or your state Solar United Neighbors chapter. Avoid door-to-door sales; the FTC cooling-off rule is 3 business days (7 in Ohio).
Enrol in your utility's DR program now
Smart thermostat BYOT, water-heater CTA-2045, managed EV charging programs pay $25 to $300/year per device and do not require an install. ConEd, FPL, Duke, Xcel, NV Energy, PG&E all run them.
Track Order 2222 in your ISO
ISO-NE 1 Nov 2026, PJM 1 Feb 2028, MISO 1 Jun 2029, SPP Q2 2030. CAISO and NYISO already live. Once active, an aggregator can register your battery or thermostat into the wholesale stack. FERC fact sheet.
Plan for the 2033 step-down
The IRS credit drops from 30% to 26% on 1 January 2033, then 22% in 2034, then expires. Many state programs (NY VDER, MA SMART block, NJ TREC, IL ABP block) also tier down as MW capacity targets fill. Locking in 2026 to 2028 install pricing is worth a real-money calculation.
Common questions about US distributed energy resources.
A small-scale generator, storage device or controllable load located on the distribution grid or behind a customer meter. The five most common: rooftop solar, home batteries (Tesla Powerwall, Enphase IQ Battery, Franklin aPower), EV chargers with managed charging, smart thermostats and connected water heaters, microgrids at homes, schools, hospitals and military bases. The defining feature is location: a DER sits at or near the point of consumption, not in a remote power-plant park.
EIA tracks small-scale solar PV (under 1 MW per system) at roughly 80+ GW nameplate capacity as of Q1 2026, which already exceeds total US installed nuclear capacity of about 95 GW (and behind-the-meter solar generates more than nuclear during the day). Counting all behind-the-meter systems plus larger commercial rooftops and parking-lot canopies, distributed solar is on track to pass 150 GW nameplate by 2026 to 2027. Source: EIA Monthly Energy Review, verified May 2026.
It forces ISOs and RTOs under FERC jurisdiction (PJM, MISO, NYISO, ISO-NE, SPP, CAISO, all except ERCOT) to let aggregated DERs compete in wholesale energy, capacity and ancillary-service markets. An aggregator (a software platform or retail supplier) bundles many small homes or businesses into a single bid that meets the ISO's minimum size requirement. The customer gets a share of the wholesale revenue back through the aggregator. Implementation is staggered: ISO-NE 1 November 2026, PJM 1 February 2028, MISO 1 June 2029, SPP Q2 2030. Source: FERC Order 2222 fact sheet.
Older Net Energy Metering (NEM 1.0 and 2.0) credited every exported kWh at the full retail rate (typically 25 to 35 ¢/kWh on PG&E, SCE, SDG&E). Under the Net Billing Tariff (NBT, or "NEM 3.0") in force since April 2023, exports are compensated at avoided-cost (Avoided Cost Calculator) rates, typically 5 to 8 ¢/kWh. The shift cuts the export value by 70 to 80% and pushes the residential business case toward solar + battery + self-consumption, not export. PG&E, SCE and SDG&E new customers are all on NBT.
The Value of Distributed Energy Resources Value Stack, launched in 2017 by the NY PSC under the Reforming the Energy Vision (REV) docket. Instead of crediting solar exports at the flat retail rate, VDER pays a per-component price that adds up: energy value (wholesale LMP at the customer's zone), capacity value (NYISO ICAP), Demand Reduction Value (DRV, time-and-location specific), Locational System Relief Value (LSRV, geographic), and Environmental Value (E-value, currently $25.10/MWh in 2026). NY thus prices the externalities and the locational benefits, instead of subsidising export at retail. Source: NY PSC VDER page.
The Residential Clean Energy Credit: 30% of installed cost of qualifying solar, battery (3 kWh+), geothermal, small wind, fuel cell, biomass. Restored to 30% by the Inflation Reduction Act of 2022, locked at 30% through 2032, then 26% in 2033, 22% in 2034, expires 2035. No cap. Carries forward to future tax years if you cannot use it all. Form 5695. Source: IRS Residential Clean Energy Credit.
Depends on your ISO. Today (May 2026): CAISO and NYISO already have DER programs running. ISO-NE opens its Order 2222-compliant aggregation on 1 November 2026. PJM launches 1 February 2028. MISO: 1 June 2029. SPP: Q2 2030. ERCOT has its own state-jurisdictional ADER pilot under PUCT supervision. You join through an aggregator (Sunrun, OhmConnect, Voltus, CPower, Octopus, Span, etc.); the aggregator handles ISO settlements and shares the revenue.
Yes, by nameplate. Behind-the-meter and small-scale solar PV is at roughly 80+ GW nameplate in early 2026, while US installed nuclear is roughly 95 GW. Two caveats. Nuclear runs at ~93% capacity factor, residential solar at ~17% to 22% depending on location, so nuclear still generates several times more annual energy. And nuclear runs at night while solar does not. But for daytime grid impact and for the consumer-cost-of-electricity calculation, behind-the-meter solar is the bigger lever already.
Keep learning about distributed energy and US markets
Wholesale electricity markets
The seven US ISO/RTOs, marginal pricing and the July 2025 PJM record auction.
Who regulates US energy?
FERC, the state PUCs, NERC, DOE, EPA and consumer advocates.
Incumbent electricity suppliers
The legacy utilities that own the wires and provide default supply.
Transmission vs distribution
The two wires layers, why they are billed separately and who is responsible.
Demand response
Getting paid to use less. How aggregated demand bids into the wholesale market.
Deregulated states map
State-by-state status of electricity and natural gas retail choice.
Electricity prices per kWh
EIA-verified state-by-state residential prices, May 2026.
Plant to plug: the journey
How your electricity gets from a power plant to the outlet at home.
New York: 1998 to 2026
NYISO, VDER and the role of the NY PSC.
Community solar
How shared solar projects let renters and non-roof-owners join in.
Texas energy hub
ERCOT, EnergyShare net metering, ADER pilot and battery economics.
Illinois: ComEd, Ameren and PJM
CEJA, the IL Adjustable Block Program and distributed generation rebates.