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A Lithuanian industrial site’s roughly 1 MWh battery created an average of about €1,960 per installed MWh per month in electricity-bill value from April to July 2026, according to Inion Software. The figure reflects day-ahead price optimization and onsite solar use, not net profit or earnings from balancing markets; annualizing it is only an indicative extrapolation.
Four months of data from an industrial battery in Lithuania show average electricity-bill value of about €1,960 per installed MWh of capacity per month, according to Inion Software. The result, measured from April through July 2026, came from shifting the site’s electricity use around day-ahead prices and available solar power; it is not measured income from electricity trading or balancing services, nor a net-profit figure.
The example site has its own solar installation and a battery rated at approximately 1 MWh of capacity and 0.5 MW of power, a configuration commonly described as a two-hour system. The site bought electricity at the Nord Pool day-ahead price for Lithuania, with a supplier margin and network charge added. It received no payment for electricity exported to the grid during the period analyzed.
From April to July, Inion’s software scheduled charging when electricity was cheaper or solar generation was in surplus, then discharged the battery when the site would otherwise have bought more expensive power. The company reported monthly value ranging from €1,640 to €2,230 per installed MWh. About 43% of charging energy came from the site’s solar installation and 57% from the grid. The battery averaged approximately 0.8 equivalent full cycles per day.
In July, the average electricity price during charging was €0.070 per kWh, compared with €0.145 per kWh during discharge, a reported difference of roughly €75 per MWh. Across the batteries in the dataset, discharged energy was 93% to 97% of charged energy; Inion says those efficiency losses are included in its value calculations.
What the Savings Figure Captures
The data offer a concrete example of how a battery can reduce an industrial site’s electricity bill, but they also show why a headline earnings estimate may not transfer from one project to another. The first site’s result depends on its solar output, consumption pattern, contract, network charges and operating strategy, as well as the battery itself. A second, similarly sized battery used mainly to increase onsite solar consumption while subject to an export constraint produced about €460 per installed MWh in July—roughly one-quarter of the first site’s reported monthly value.
That gap matters to businesses evaluating storage investments: battery capacity alone does not determine the financial outcome. Export rights and tariff structures can materially affect the value available to an owner. The figures are also not net profit. Inion says its calculation excludes degradation, financing, fixed network charges and possible trading or aggregation fees, among other costs.
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From Site Savings to Market Revenue
Inion CTO Robertas Janickas presented the results as evidence that there is no single earnings figure for every battery. The company’s software can exchange data for offers in frequency containment reserve (FCR), automatic frequency restoration reserve (aFRR) and manual frequency restoration reserve (mFRR) markets. However, the batteries covered by this dataset had not participated in those markets, so the report provides no measured revenue split from balancing services or wholesale trading.
The report multiplies the four-month average by 12 to give an indicative figure of about €23,500 per installed MWh per year. That is a simple extrapolation, not an observed annual result: the measurements cover spring and summer only, and do not establish what the battery would earn through a full year of changing prices and site conditions.
Operational performance also affects the economics. Inion reported that its controller normally confirms a command within 0.5 to two seconds, while the battery’s median power response took 39 seconds. The slowest 10% of observed responses took up to 11 minutes, with delays often linked to changes between idle and active states. The company says response times varied by battery model and requested transition.
“There is no one-size-fits-all solution.”
— Robertas Janickas, CTO at Inion Software
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Costs and Full-Year Results Remain Open
The four-month sample does not show whether the reported monthly value would hold across autumn and winter, when solar generation, consumption and electricity prices may differ. The €23,500 annual figure is not measured performance, and the report does not provide a complete accounting of net returns after ownership and operating costs.
There is also no measured evidence here of earnings from FCR, aFRR, mFRR or intraday trading, because the batteries in the dataset had not entered those markets. Inion notes that metering errors can change calculated battery value, while connection failures or schedules that are not followed can erode returns. The report does not disclose enough detail to independently compare the two sites’ full contract and tariff structures.
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Testing Controls Before Market Entry
For owners considering storage, the report points to accurate metering, a tested control connection and an electricity contract suited to the intended use as practical starting points. Battery response should also be measured for the specific model and operating transitions; slow or inconsistent execution could undermine a schedule or affect performance in faster-response services.
In Lithuania, balancing offers start at 1 MW and increase in 1 MW increments, while commercial and industrial batteries are commonly rated at 0.1–0.5 MW, according to the report. Many individual sites would therefore need to join an aggregated portfolio to reach the offer size. Whether these batteries later participate in balancing markets, and what revenue they earn there, remains unreported.
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Key Questions
How much value did the Lithuanian battery create?
Inion reported an average of about €1,960 per installed MWh of capacity per month from April to July 2026 at one industrial site. Monthly results ranged from €1,640 to €2,230 per installed MWh.
Is that figure net profit?
No. It represents electricity-bill value from day-ahead price optimization and solar use. The calculation excludes costs such as battery degradation, financing, fixed network charges and possible trading or aggregation fees.
Did the battery earn money from balancing markets?
The report gives no measured balancing-market earnings. The batteries in the dataset had not participated in FCR, aFRR or mFRR, despite the platform’s ability to exchange data for those offers.
Can the monthly result be treated as an annual forecast?
No. Multiplying the four-month average by 12 gives an indicative figure of about €23,500 per installed MWh per year, but the data cover only April through July. It is not a measured full-year result.
Why did another battery produce less value?
A second, similarly sized system produced about €460 per installed MWh in July while focusing mainly on onsite solar use under a grid export constraint. Inion says export permissions, tariffs and operating strategy can affect results alongside battery hardware.
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