VPP money trail · two-way orchestrated
Who gets paid when an orchestrated virtual power plant trades every day
Follow one peak day of a Texas battery fleet dispatched by ERCOT every five minutes: midday charging, evening sales, fixed owner credits, and who keeps the swing.
VPP Economics has no affiliation with, sponsorship from, or endorsement by any utility, aggregator, platform, or device maker named here.
The short answer
- An orchestrated virtual power plant (VPP) trades every day. In Texas, aggregated home batteries in ERCOT’s Aggregate Distributed Energy Resource (ADER) pilot bid into the wholesale market, are dispatched every five minutes, and send telemetry back every two seconds (ERCOT; Base Power).
- On a representative peak day a 10 megawatt (MW) fleet earns about $8,196 from ERCOT, almost all of it from selling stored energy in the evening, after paying about $1,067 to charge at midday.
- Owners usually get a fixed credit, and the fleet operator keeps the swing. At $400 a year per battery, owner credits cost $2,192 a day. The operator keeps about $4,937 on the peak day but would be about $1,370 short on an average day.
- This is the opposite of event-based demand response (DR): hundreds of dispatches a year, money flowing both ways, and value driven by energy prices rather than a capacity payment.
Money trail for one day of a two-way orchestrated VPP
Who pays whom, and who carries the risk, for one peak day in ERCOT. Representative fleet; inputs marked published or assumed.
Swipe to see the full chart →
Step by step
- Electricity customers in Texas buy power at prices set in ERCOT’s real-time market, passed through their retail plans.
- Retail electric providers are the load-serving entities. They buy their customers’ power from ERCOT, so the fleet’s evening sales are paid for out of that settlement.
- ERCOT runs the market every five minutes, co-optimizing energy and reserves, and settles both directions: it pays for energy sold and reserves held, and charges for energy used to charge (ERCOT).
- The fleet operator is a qualified scheduling entity (QSE) and often also the retail provider and battery maker — Tesla Electric is all three. It forecasts prices, submits bids, and splits each five-minute instruction across batteries by state of charge (Tesla).
- Batteries and the device cloud follow the instructions and report back. ERCOT requires resource-level telemetry every two seconds and, for aggregated telemetry, one-minute device-level sub-meter data (ERCOT).
- Battery owners receive a fixed credit on their retail bill and keep a backup reserve; the operator uses the rest of the stored energy.
- The local wires utility (the transmission and distribution service provider) moves no cash in this flow but supplies interval meter data for settlement.
Who carries the risk
The fixed credit is the key design choice. Tesla Electric’s Fixed plan pays $400 a year per Powerwall, up to three (Tesla). Other Texas programs pay $200 a year to Sunrun system owners (Sunrun), $150 every six months through TXU (TXU Energy), and $50 a month through Reliant Battery Perks (Reliant). Owners get a predictable check; the operator takes the market risk.
That risk is real. ERCOT prices were lower in summer 2026 than in 2024 or 2025 (ERCOT), and an average grid-scale battery earned about $30 per kW over the trailing twelve months, with ancillary services falling to 28% of revenue (Modo Energy). At that benchmark this fleet would earn about $300,000 a year in the market against $800,000 in owner credits.
That gap suggests operators value these fleets for more than wholesale trading — for example, retail plan margins, customer retention, hardware sales, and the option on larger pilot limits and tighter future markets. This is our inference; operators don’t publish fleet economics.
There is a market-linked alternative. Tesla Electric’s Dynamic plan pays 90% of the real-time price for exported stored energy plus $10 a month per Powerwall (Tesla). On this peak day, a battery exporting 10 kWh at about $400/MWh would earn about $3.93, against $1.10 a day on the fixed credit; on quiet days it would earn less.
What it means
Utilities and retail providers
A fleet that discharges into the evening ramp lowers the price everyone pays. Retailers that run fleets also hedge their own supply cost, which is why many Texas programs come bundled with a retail plan.
Program managers
Fixed credits make enrollment easy but hide the market value. Note that the $781 peak on August 26 came after battery discharge had already peaked — duration and state of charge matter as much as kW.
Aggregators
The business is a spread: market revenue minus charging cost minus fixed owner credits. A few spike days carry the year, so forecasting and keeping energy in reserve for late peaks are the edge.
One-way event versus two-way orchestrated
Demand response event
A handful of calls a year, a dispatch signal that only goes out, and performance checked afterward against a baseline built from meter data. Most of the value is capacity, paid per kilowatt (kW) for being available.
Market-traded fleet
Dispatched every five minutes, every day, with live telemetry flowing back to the grid operator. Most of the value is energy bought cheap and sold dear, plus reserves; Texas has no capacity market.
See the one-way demand response money trail → Or see how a per-kilowatt-hour program pays in the PG&E emergency program money trail →
All six money trails
PJM demand response event
Capacity is most of the value; owners get a contract share.
See the money trail →Per kWh · one-wayPG&E emergency event
$2 per kWh delivered, passed through to owners.
See the money trail →Flat per devicePSEG Long Island thermostats
$25 a year per device, however many events.
See the money trail →Time-of-use · no programSCE battery on a TOU rate
Bill savings from a price signal, not a dispatch.
See the money trail →Hosted hardwareBase Power home battery
The company owns the battery and keeps the grid value.
See the money trail →Two-way · orchestratedERCOT market-traded fleet
You are here. Traded every day; owners get a fixed credit.
This pageMethod and caveats
Representative example, not a specific company’s fleet. Assumes 2,000 batteries of 5 kW and 13.5 kWh, discharging 10 MW for two hours (10 kWh each, above a 25% backup reserve), 90% round-trip efficiency, an average evening sale price of $400/MWh, and 5 MW of Non-Spin reserve held for ten hours. The hourly price shape is stylized around published anchors, not the actual settlement-point prices.
Owner credits are spread evenly across 365 days. The average-day comparison applies a grid-scale benchmark that home fleets may beat (longer duration) or miss (pilot limits, reserve requirements). Gross payments are not net profit: the operator pays for telemetry, market registration, software and customer service. Checked October 16, 2026.