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Evaluate thermal energy storage (TES) as part of the plant’s heat-delivery system—not as a standalone battery. First define the heat service the process needs, then compare viable charging and delivery configurations on the same operating, cost and emissions assumptions. A storage project is worth pursuing only if it can provide the required heat quality, power and availability while fitting the plant’s schedule and economics.
Start with the heat the process needs
A nameplate capacity in megawatt-hours does not tell you whether a store can serve a particular process. The useful service depends on temperature, when heat is needed, how quickly it must be supplied and how much interruption the process can tolerate.
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Build a heat-demand profile before comparing technologies. Gather:
- Process supply and return temperatures, including the required delivery temperature and any temperature glide.
- Hourly and seasonal heat demand, with minimum, typical and peak loads.
- Production schedules, ramp rates, shutdown periods and required uptime.
- Whether loads can be interrupted or shifted, and for how long.
- Heat demand separated by process and temperature, so low-temperature uses are not hidden inside a high-temperature total.
- The project’s primary objective: displacing fuel, shifting electricity use, integrating renewable energy, reducing peak demand, improving resilience, lowering emissions, or combining these services.
These inputs set the required discharge temperature, usable capacity, thermal power and storage duration. They also reveal whether the plant needs continuous heat, a short peak-shaving window or some other dispatch pattern.
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Define the baseline and the configurations to compare
Document the existing heat system before assigning value to storage. Record the boilers, furnaces, heat recovery, steam network, heat pumps and electric boilers in service; their efficiencies, operating schedules and maintenance needs; and their remaining service lives. Include existing backup arrangements and any constraints on the grid connection or heat-transfer network.
For each proposed configuration, state what charges the store, when charging occurs, how stored heat reaches the process, what incumbent equipment remains available and how controls coordinate with production. Compare direct thermal storage separately from systems that store electricity and later convert it back to heat or power. The energy pathway and system boundary affect both efficiency and cost.
| Configuration | What to establish | Key comparison |
|---|---|---|
| Direct heat storage | Heat source, storage medium and vessel, temperature range, heat exchanger and process tie-in. | Whether stored heat can reach the process at its required temperature and schedule without an unnecessary heat-to-electricity-to-heat conversion. |
| Electric boiler plus storage | Charging hours, electric-boiler capacity, storage dispatch and role of retained boilers. | Whether shifting electricity use improves the modeled cost or operational flexibility enough to justify storage and integration costs. |
| Heat pump plus storage | Source and delivery temperatures, heat-pump capacity and added equipment cost, charging window and storage dispatch. | Whether storage’s operating savings exceed the costs of storage and any added heat-pump capacity for this site. |
| Incumbent boiler or furnace without storage | Fuel use, efficiency, operating pattern, maintenance, remaining life and expected costs. | The counterfactual: what costs, emissions and operational risks the proposed project would actually avoid. |
These are screening categories, not interchangeable designs. DOE distinguishes industrial process-heat uses from storage pathways intended to produce power, and notes that industrial applications are case-specific. Using heat directly can avoid the energy penalty of converting heat to electricity and back to useful heat; that is a different economic case from grid-scale electricity storage. DOE’s thermal energy storage technology assessment describes the distinction.
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Screen technical fit, capacity and integration
For every credible configuration, assess performance at the process boundary—not only at the storage vessel. Request comparable values and assumptions for:
- Heat quality: charge and discharge temperatures, temperature glide and delivered temperature under expected operating conditions.
- Usable capacity: thermal energy deliverable at the required temperature, rather than nominal nameplate capacity alone.
- Power and duration: maximum charge and discharge rates, hours of delivery at the required load, annual cycles and response to variable production.
- Losses and auxiliary demand: heat loss during storage, parasitic electricity, conversion steps and control requirements.
- Plant integration: footprint, piping and electrical tie-ins, steam or heat-transfer-fluid compatibility, outage duration and impact on production.
- Materials and upkeep: compatibility, corrosion or degradation risks, safety provisions, maintenance access and replacement needs.
- Reliability: expected operating life, availability assumptions, performance guarantees and the backup equipment needed if storage is unavailable.
Require the supplier or engineer to identify the measurement boundary behind every efficiency or capacity figure. A round-trip efficiency for a system that converts electricity into heat and later generates electricity is not the same metric as usable heat delivered to an industrial process. The available sources do not establish one universal industrial TES efficiency, lifetime or cost.
Build an hourly cost case, not an annual-average one
Model dispatch against the plant’s actual production schedule and local prices over time. Annual average electricity and fuel prices can conceal whether the store can charge when electricity is inexpensive, whether the plant can use the heat later and what demand or network charges apply.
Include the full project boundary: electricity and fuel; taxes and levies; demand and network charges; grid connection; charging equipment; storage medium and vessel; heat exchangers; power conversion, if applicable; controls; engineering and construction; integration outage; operations and maintenance; financing; replacements; and decommissioning. Credit avoided fuel and any verifiable demand-response or flexibility revenue, but do not count the same benefit twice.
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One free scan finds every outdated or missing driver and matches the right update for your exact hardware.Free scan · exact hardware matchCompare delivered heat cost and total installed cost against the incumbent system and against other feasible configurations. State the assumptions alongside each result, especially utilization, annual cycles, storage duration, efficiency, asset life, discount rate and future tariffs. Stress-test changes in:
- Electricity-to-fuel price ratios and charging windows.
- Capacity factor, annual cycles and the duration of each discharge.
- Installed capital cost, efficiency, lifetime and replacement schedule.
- Grid capacity, tariff structure and demand charges.
- Financing assumptions and production availability.
Published cost comparisons can omit costs or benefits that matter to a particular site. The IEA’s 2025 chart of levelised industrial heat costs from heat pumps by country uses Eurostat electricity costs, network charges and taxes, excludes VAT as generally reimbursable, and excludes additional upfront grid-connection costs and potential frequency ancillary-service revenues. Those boundaries should be checked before comparing a chart value with a project proposal. See the IEA chart and its stated scope.
In a separate IEA factory analysis, modeled cases found that adding TES while retaining existing boilers could reduce levelised cost for electric boilers; the modeled benefit was smaller for heat pumps, and added heat-pump capital could offset storage savings. Those are results of that analysis’s assumptions, not a general rule that storage makes one configuration cheaper. Read the IEA factory analysis.
Evaluate emissions and operating value separately
Estimate emissions using an explicit electricity emissions basis and the fuel actually displaced. If the analysis uses electricity emissions, state whether they are annual-average or marginal; the choice can change the result. Charging during lower-price hours does not necessarily mean charging during lower-emissions hours.
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Use published figures as context, not as a site forecast
Examples and sector statistics can show that a technology or application is being discussed or deployed; they do not establish performance or cost at another plant.
- Hungary project: The IEA reported 56 MWh of electrified heat and thermal storage at a corn-processing plant in Hungary in its 2025 factory analysis. The cited passage does not identify the detailed storage design or provide verified cost and operating performance, so the figure indicates reported project scale only. IEA factory analysis.
- Heat-pump technical potential: The IEA’s 2026 Heat Pump Monitor says commercially available industrial heat pumps could technically supply up to around 20% of global industrial heat demand, mainly in low- and medium-temperature processes. This is technical potential, not current deployment or a measure of TES’s share. IEA Heat Pump Monitor key findings.
- Low-temperature industrial energy: The IEA’s 2024 Renewables for Industry executive summary attributes roughly 70% of global industrial energy consumption to industries relying primarily on low-temperature heat and steam processes. This is not the share of heat demand that storage can serve. IEA executive summary.
- Heat-pump cost range: The same 2024 IEA executive summary gives a modeled range of 41–74 EUR/MWh for industrial heat pumps compared with gas boilers across several EU member states, with variation attributed to electricity prices and energy-tax and network-cost treatment. It is a dated, geography-specific modeled range—not a current quote or a universal project benchmark. IEA executive summary.
- Grid-storage performance figures: DOE’s 2023 assessment estimates 44% round-trip efficiency and a 35-year storage-block calendar life for a specific 2030 molten-salt storage-with-steam-turbine grid-storage case. These figures are not representative values for every thermal store or for direct industrial heat delivery. DOE Storage Innovations 2030 assessment.
Validate the proposal before committing capital
Before investment, require evidence that connects the proposed equipment to the plant’s actual operating conditions. A project package should include:
- A process-integration study and measured or otherwise defensible interval load profile.
- An equipment-boundary diagram showing charging, storage, heat delivery, backup and controls.
- Performance guarantees tied to specified inlet and outlet conditions, usable capacity and discharge rate.
- Transparent assumptions for degradation, maintenance, replacements, availability and operating life.
- A commissioning and acceptance plan, safety review and defined responsibility for integration work.
- An editable economic model with assumptions that the plant can stress-test.
For a first-of-a-kind or emerging configuration, consider a staged pilot or demonstration with measurable acceptance criteria and a fallback operating plan. A site-specific decision still requires local facility and tariff data; published examples cannot substitute for process engineering and an hourly operating model.
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