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Google is backing Energy Dome, an Italian company developing long-duration energy storage with a closed-loop carbon-dioxide system. The technology has been demonstrated at commercial scale in Sardinia, and Google-linked projects are planned in Ireland and Arizona. Those plans are not a fleet of operating Google-owned plants: the announced Ireland and Arizona facilities are still in development, and Energy Dome—not Google—is set to own and operate them.
What Google announced—and what it did not
On July 25, 2025, Google announced a strategic investment in Energy Dome and a commercial partnership to develop energy-storage projects in Europe, North America and Asia-Pacific. The aim is to make longer-duration storage available to support Google’s goal of matching its electricity use with carbon-free energy around the clock. Google’s announcement and Energy Dome’s partnership announcement describe a project pipeline, not a set of facilities already built across those regions.
The distinction matters. Google can invest, contract for clean-energy benefits or help provide a project with a commercial customer without owning or operating the plant. In the two announced projects most directly linked to the partnership, Energy Dome is the developer and planned owner-operator. In Arizona, utility Salt River Project (SRP) is to dispatch the stored electricity. These are grid-scale projects, not batteries installed at Google data centers.
Where the projects stand
The announced projects have different ratings and statuses. “200 MWh” is a useful shorthand for some of Energy Dome’s systems, but it is not the rating of every project.
| Location | Rating | Status and target | Commercial arrangement |
|---|---|---|---|
| Ottana, Sardinia, Italy | 20 MW / 200 MWh | Commercial-scale reference plant; Google said it had demonstrated operation on the Italian grid. | Energy Dome announced a storage offtake agreement with ENGIE; this is not identified as a Google-owned facility. Energy Dome–ENGIE announcement |
| Near Rhode, County Offaly, Ireland | 23 MW / 200 MWh | Planned; expected online in 2028. Energy Dome says it has secured land, planning consent, grid connection and a 10-year capacity contract from EirGrid. | Energy Dome is to develop, own and operate the project. A second 200-MWh unit is planned at the site. Energy Dome’s Ireland project announcement |
| Coronado Generating Station, St. Johns, Arizona | 19 MW for 10 hours—about 190 MWh by power multiplied by duration | Planned; SRP expects it online in 2029. The project is also intended to test performance in Arizona’s climate. | Energy Dome is to own and operate the system; SRP will dispatch it under a 20-year tolling agreement. SRP project page |
Google’s Ireland announcement provides additional project context: Google Ireland’s announcement. The Arizona project details are also set out in Energy Dome’s project announcement. Target dates are expectations, not confirmation that construction or commissioning is complete.
How a CO₂ Battery stores and returns electricity
Despite the name, Energy Dome’s system is not an electrochemical battery like lithium-ion. It is a closed thermo-mechanical cycle: carbon dioxide serves as a working fluid, and industrial machinery converts electricity into stored pressure and heat, then back into electricity. Energy Dome’s technology description distinguishes its standalone CO₂ Battery from its separate CO₂ Battery Plus configuration, which integrates with gas-turbine generation.
Charging
- Electricity powers compressors, raising the pressure of gaseous CO₂.
- As it is compressed, the CO₂ becomes liquid. Heat created during compression is captured and stored for use during discharge.
Discharging
- When electricity is needed, the liquid CO₂ is heated and allowed to expand back into a high-pressure gas.
- The expanding gas drives a turbine connected to a generator, delivering electricity to the grid.
- The CO₂ returns to its gaseous state and is reused in the cycle.
The system does not make or consume CO₂ as fuel in this cycle. Nor is it carbon capture: the working fluid circulates in a closed system rather than being removed from the atmosphere or permanently stored underground. A leak would reduce the working-fluid inventory and could create an industrial-gas hazard; project-specific safety details are not established in the public announcements cited here.
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What a 200-MWh rating means
MW measures power—the rate at which a plant can deliver electricity. MWh measures energy delivered over time. A 20-MW system rated at 200 MWh could, in simple arithmetic, supply 20 MW for 10 hours. It does not mean the plant produces 200 MW, nor that 200 MWh is available under every operating condition.
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- Sardinia: 20 MW / 200 MWh corresponds to a nominal 10-hour duration at rated output.
- Ireland: 23 MW / 200 MWh corresponds to about 8.7 hours at rated output.
- Arizona: SRP and Energy Dome describe a 19-MW, 10-hour system, or about 190 MWh by direct calculation. It should not automatically be reported as exactly 200 MWh.
These calculations describe rated power multiplied by duration, not a guarantee of usable output in every circumstance. Storage also has round-trip losses: it takes more electricity to charge a system than it later returns. The cited project announcements do not establish a project-specific, independently verified round-trip-efficiency figure.
Why Google is interested in longer-duration storage
Wind and solar output does not always coincide with electricity demand. Solar generation can be abundant during the day and fall in the evening; wind output can vary with weather. Storage can shift some electricity from periods of surplus to later hours, helping manage evening peaks, renewable oversupply and grid congestion.
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That timing matters to data centers, whose electricity demand can be substantial and continuous. Google’s 24/7 carbon-free-energy goal is more demanding than matching annual electricity use with an equivalent volume of renewable-energy purchases: it seeks carbon-free supply on an hourly basis. Storage is one possible way to align clean generation with demand when the two do not occur at the same time.
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How Energy Dome’s model fits the partnership
Energy Dome markets an “energy storage as a service” approach: it can develop, finance, build, own and operate a plant, while a customer or utility contracts for its storage capacity or output over time. The company’s service description says a standard 200-MWh plant needs about 5 hectares (12 acres) of relatively flat land and a medium-voltage electrical connection. That footprint is a vendor estimate, not an independently verified site requirement for every project.
The contracts announced in Ireland and Arizona illustrate why the commercial structure matters. Ireland has a 10-year capacity contract; Arizona has a 20-year tolling agreement under which SRP dispatches the facility. Long-term arrangements can provide revenue certainty for infrastructure investment. They also mean a project’s case depends on contract terms and local market rules, not just buying electricity cheaply and selling it later.
Potential advantages—and the trade-offs
Where the approach may fit
- Longer discharge windows: A system designed for roughly ten hours can address needs that extend beyond a short peak-shaving period.
- Different equipment and materials: Compressors, heat exchangers, turbines, pressure vessels and CO₂ replace lithium-ion cells as the core storage mechanism. This may reduce exposure to some battery-mineral constraints, but it does not eliminate supply-chain, construction or equipment risks.
- Industrial sites: The announced Ireland and Arizona projects are associated with former or existing thermal-generation sites. Such locations may offer industrial land and grid infrastructure, although each site still needs suitable connections, permits and engineering.
- Potential siting flexibility: Energy Dome’s stated land requirement is modest relative to some utility-scale storage concepts, but actual land and connection needs vary by project.
What remains uncertain
- Efficiency and cost: Public project announcements cited here do not disclose independently verified project efficiency or transparent, comparable project prices. Energy Dome describes the technology as cost-competitive, but that claim is not an apples-to-apples cost comparison with current lithium-ion installations.
- Maintenance and durability: Rotating machinery, heat exchangers and pressurized equipment bring different maintenance needs from battery cells. Public announcements do not settle component life or long-term operating costs.
- Climate transferability: SRP says the Arizona project will test operation in its local climate. Results in Sardinia or Ireland cannot simply be assumed to transfer to Arizona heat.
- CO₂ lifecycle details: The described cycle reuses CO₂, but public project materials cited here do not fully specify sourcing, purity, lifecycle accounting or replacement practices for every project.
- Carbon impact: A storage plant can return electricity charged from low-carbon generation, but it does not make its equipment, construction or charging energy impact-free. “Carbon-free” describes the electricity service only when the charging supply and accounting support that claim.
- Execution risk: Announced facilities still have to be built, connected and commissioned. Even a project with key approvals may face construction and operating challenges; future pipeline projects can also encounter permitting and interconnection delays.
How it compares with other storage options
No storage technology is the universal winner. A buyer or grid planner needs to compare duration, round-trip efficiency, siting, construction time, degradation, safety, supply chain and available revenue—not just the name of the storage medium.
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|---|---|---|
| Lithium-ion | Established, responsive and modular; widely used for shorter-duration grid storage. | Duration, degradation, fire-safety design and mineral supply-chain exposure need project-specific assessment. |
| Pumped hydro | Mature option for large storage volumes and long asset life. | Requires suitable geography and water resources, major civil works and often lengthy permitting. |
| Flow batteries | Can scale energy capacity by increasing electrolyte tank volume, making longer durations a potential use. | Economics and commercial maturity vary; the system has its own electrolyte and equipment requirements. |
| Compressed-air storage | Can store energy for long periods using pressurized air and turbines. | Some designs depend on suitable underground geology; alternatives may require large pressure vessels. |
| Hydrogen | Potentially useful for multi-day or seasonal storage and for linking power with industrial or fuel markets. | Electricity-to-electricity conversion typically involves substantial losses and requires electrolyzers, storage and turbines or fuel cells. |
| CO₂ Battery | Thermo-mechanical approach aimed at long-duration grid storage using industrial equipment and a closed CO₂ working-fluid loop. | Project-level efficiency, cost, maintenance record and large-scale replication need to be demonstrated. |
What to watch next
The meaningful test is not the global language of the partnership but whether the named projects reach operation and perform as intended. For Ireland, the next milestones are construction progress toward the expected 2028 online date; for Arizona, delivery of the 19-MW, 10-hour system toward SRP’s 2029 target and evidence from its hot-climate operation. Performance data, actual costs, maintenance experience and additional contracted projects will show whether Energy Dome’s approach can be replicated at scale.
For Google, another open question is how each project’s electricity or capacity will contribute to its carbon-free-energy accounting. The partnership and project announcements establish commercial support and grid-storage plans, but do not by themselves quantify how much clean electricity Google will receive from each facility.
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