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Industrial heat pumps are a practical option for many low- and medium-temperature duties, but a successful installation depends on four site-specific tests: a usable heat source, the required process temperature and pressure, enough electrical capacity, and an integration plan that fits production. The International Energy Agency (IEA) says large-scale industrial heat pumps are well established up to 150°C; that is a broad technology description, not a universal limit for every machine or process. Steam production is also possible: the IEA cites a 5 MW installation at a Norwegian fishmeal manufacturer. Neither fact removes the need for plant-level engineering.
The most expensive mistakes usually happen before equipment is ordered. A factory can have an excellent waste-heat source but no grid capacity, or a strong electrical connection but a process duty that needs a pressure and temperature combination better served by an electric boiler, hybrid system or existing boiler. This guide shows how to check those constraints in the order they affect feasibility.
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What makes an industrial heat-pump project feasible?
An industrial heat pump takes heat from a source, raises its temperature, and delivers it to a process. The source may be waste heat from another process or another engineered heat source. The system does not create high-temperature heat from nothing: the higher the required temperature lift, the more demanding the design and operating economics become.
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Before selecting a model, document these six questions:
- Process duty: What temperature, pressure and heat-delivery medium must be supplied, and how does demand change by shift, batch or season?
- Heat source: Is heat available at the required location, temperature and flow for the hours the process needs it?
- Electrical connection: What additional peak demand will the installation create, and can the site obtain that capacity on the required schedule?
- Integration: Can the equipment connect to existing heat exchangers, steam lines, condensate systems and controls without unacceptable production downtime?
- Flexibility: Can storage or operating schedules move electricity use without disturbing production?
- Economics: How do electricity and fuel prices, utilisation, connection works, capital cost and maintenance compare for this site?
A project is not ready for final equipment selection until each answer is supported by measured plant data or a documented engineering assumption.
Grid capacity and connection lead time
Electrifying heat adds load to the plant’s electrical system. The relevant question is not simply whether the factory has a high-voltage connection today, but whether the connection, transformers, switchgear and network can carry the heat pump’s coincident peak while the rest of production is operating.
Measure the existing and future load
Build a load profile using interval meter data rather than a single nameplate total. Record current peak demand, normal and maximum operating hours, seasonal changes, motor starts, planned production expansion and other electrification projects. Add the heat pump’s expected electrical demand under the operating conditions that create its highest load. If auxiliary pumps, fans, electric backup heaters or water treatment are required, include them in the same assessment.
Ask the distribution or transmission utility for the available import capacity at the connection point, the required studies, protection changes, network-reinforcement scope and the validity period of any offer. A connection that appears adequate on average may still fail a peak-demand or short-circuit assessment.
Allow for a long connection process
The IEA reports that securing grid connections can take several years in some contexts. “Several years” is not a universal lead-time estimate: the actual period depends on country, network congestion, voltage level, permitting and the work required at the site. It is nevertheless long enough to affect a heat-pump project’s schedule if grid planning starts after the equipment has been specified.
The IEA’s policy recommendation is to “Anticipate heat electrification in long-term grid planning and prioritise connection requests with demand side flexibility to prevent capacity shortages and reduce project delays.” Read the full recommendation in the IEA executive summary. In practice, involve the utility during the concept phase, not after a purchase order.
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Check whether flexibility helps
If the process can shift heat production, a hot-water or steam accumulator, buffer tank or other thermal-storage arrangement can charge when electricity is available and discharge during production peaks. Controls may also limit simultaneous operation of other large loads. These measures can reduce coincident peaks or improve tariff exposure, but they do not guarantee that a network upgrade can be avoided. Storage volume, discharge temperature, allowable pressure variation and the length of the production interruption must be calculated from the actual duty.
Document the operating rule explicitly: for example, whether the heat pump follows electricity price, a grid import limit, a storage state of charge or a production schedule. A flexible control strategy that cannot protect process quality is not a usable solution.
Heat-source availability and temperature lift
The source side is often the decisive constraint. A heat pump may recover heat from warm wastewater, cooling circuits, exhaust streams or another process, but the source must be available when the sink needs heat and must be physically connectable to the equipment.
Characterise the source over time
Measure source temperature and flow at representative operating points, including start-up, shutdown, cleaning, product changes, weekends and seasonal conditions. Record how many hours the source is available and whether its temperature falls when production is reduced. A one-time temperature reading can overstate the useful resource.
Also test:
- Contamination and fouling: Solids, oils, chemicals and biological material may require an intermediate heat exchanger, filtration or a cleaning regime.
- Hydraulic compatibility: Check flow, pressure drop, pump capacity and safe isolation points.
- Location: Long pipe runs can add cost, heat loss and control complexity.
- Reliability: Identify what happens during source outages, maintenance or abnormal production.
- Environmental limits: Confirm discharge, cooling and refrigerant-related requirements with the project’s engineers and authorities.
Calculate the temperature lift
Temperature lift is the difference between the heat-source temperature available to the heat pump and the temperature required at the process interface. A source that is too cool may still be usable, but a larger lift generally requires a different compressor arrangement, more electrical input, staged heating or backup heat. The result can be lower efficiency and a weaker business case.
There is no universal minimum source temperature or maximum lift that can be applied to every installation. The IEA material establishes the importance of waste-heat recovery and integration, but it does not provide one design threshold for all plants. Treat source temperature, flow and availability as measured project inputs, not generic catalogue assumptions. The IEA discussion is available in “Can low-temperature heat in factories be electrified competitively?”.
Match the source profile to the sink profile
Compare a time series of source heat with the process demand. If the source is abundant at night but the process needs heat only during a daytime batch, storage may bridge the mismatch. If the source disappears during the same periods that demand peaks, storage may be too large or backup heat may be required. Size the heat pump for the duty it can reliably serve, rather than for the maximum theoretical source output.
Process temperature, pressure and the 150°C reference
The IEA’s 2025 executive summary states: “Large-scale industrial heat pumps are well established to deliver heat up to 150 °C, while electric boilers can generate steam up to 350 °C and pressure of around 70 bar.” The statement is useful for orienting a feasibility study, but it does not mean every industrial heat pump reaches 150°C, nor that 150°C is an absolute ceiling for every product or refrigerant configuration.
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Define the process requirement at the point of use. “The process needs steam” is incomplete without steam pressure, saturation temperature, dryness or quality requirements, demand variation, condensate return and allowable pressure fluctuation. A heat pump may be suitable for preheating, hot water, drying or another low-temperature stage even when it cannot economically provide the final high-temperature duty.
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Keep the IEA’s electric-boiler figures separate from heat-pump capability. Electric boilers can generate steam up to 350°C and around 70 bar in the cited report summary; those values are not specifications for industrial heat pumps.
Can an industrial heat pump make process steam?
Yes, in some applications. The IEA documents a 5 MW heat-pump installation at a Norwegian fishmeal manufacturer that produces process steam. This proves that heat-pump steam production is technically feasible in at least one industrial setting, not that the same configuration suits every steam network.
Start with the existing steam system
Collect the boiler-room and process data before choosing a steam-producing arrangement:
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- Minimum, normal and peak mass-flow demand.
- Batch timing, start-up demand and allowable ramp rate.
- Condensate return rate, temperature and contamination risk.
- Existing boiler turndown, backup capacity, feedwater treatment and blowdown requirements.
- Steam-distribution pressure losses and the location available for new equipment.
Then test whether part of the duty can be converted to hot water, hot-oil circulation or preheated feedwater. Supplying a lower-temperature duty with a heat pump and retaining a boiler or electric boiler for the final steam lift can reduce the required lift and electrical capacity.
Integrate controls and backup
A steam heat pump must coordinate with boiler firing, feedwater, condensate, pressure control, safety interlocks and production controls. Specify what happens when source heat is unavailable, the grid imposes an import limit, the heat pump trips or steam demand changes faster than the compressor can respond. Retaining a boiler as backup or peak capacity may improve resilience, but it also affects capital allocation, maintenance and emissions accounting.
The Norwegian 5 MW example does not publish enough design detail in the cited source to generalise its pressure, temperature, refrigerant, source conditions or operating schedule. Obtain those parameters from the project’s engineering documentation before using it as a design analogue. The example is discussed by the IEA at this page.
A practical feasibility workflow
Use the following sequence to avoid committing to equipment before the three core constraints are understood.
- Define the duty. Create a duty matrix for each process area: delivered medium, temperature, pressure, flow, minimum and peak demand, operating hours and quality limits.
- Measure the source. Log source temperature, flow and availability over representative shifts and seasons. Identify fouling, contamination and outage conditions.
- Model the lift. Calculate source-to-sink temperature lift at design and off-design conditions. Include heat-exchanger approach temperatures and distribution losses.
- Build the electrical case. Add compressor, pumps, fans, controls and any backup heater to the plant’s interval demand profile. Identify the resulting peak and annual consumption.
- Engage the utility. Request connection capacity, studies, network works, protection requirements, permits and an indicative schedule. Treat any “several years” risk as a schedule input until the utility provides site-specific information.
- Choose an integration architecture. Compare direct process heating, a hot-water loop, staged heat pumps, heat-pump preheating, thermal storage, electric-boiler topping and hybrid boiler operation.
- Plan the outage and controls. Map tie-in points, isolation, commissioning, cybersecurity and process-control changes. Define a fallback mode for every credible trip or source interruption.
- Evaluate economics under scenarios. Test local electricity and fuel prices, connection charges, utilisation, storage operation, maintenance, downtime and financing. Use ranges and sensitivities rather than a single payback promise.
- Validate with a staged project. Where source or duty data are uncertain, begin with metering, a pilot heat exchanger or a limited process loop before sizing a plant-wide system.
Heat pump, electric boiler, hybrid or existing boiler?
No single technology wins every duty. Compare alternatives against the same process and site data.
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| Decision axis | Industrial heat pump | Electric boiler | Hybrid or existing boiler |
|---|---|---|---|
| Best-fit duty | Low- and medium-temperature heat, especially where recoverable heat is available | Direct steam or high-temperature duty where electrical capacity is available | Mixed duties, peak demand, backup or sites with constrained source heat |
| Source requirement | Needs a suitable source with adequate temperature, flow and availability | Does not require a recoverable heat source, but requires electrical input | Can combine recovered heat with combustion or electric top-up |
| Temperature reference | Large-scale systems are described by the IEA as well established up to 150°C; actual capability is system-specific | The IEA summary describes steam up to 350°C and around 70 bar | Depends on the boiler and heat-pump stages selected |
| Grid impact | Compressor and auxiliaries add electrical demand | Often a large direct electrical load for steam generation | Can reduce peak electrical demand if combustion backup remains available |
| Integration work | Source and sink heat exchangers, controls, storage and possibly steam interfaces | Electrical, steam, feedwater and safety integration | More control modes and equipment coordination, but potentially greater resilience |
| Key uncertainty | Source profile and achievable temperature lift | Connection capacity and electricity cost | Operating complexity and the economics of retaining multiple systems |
The table is a screening framework, not a substitute for a process design. Compare delivered heat at the process boundary, not only the nominal equipment rating.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Economics, scheduling and operating strategy
Electricity-to-gas price ratios can determine whether a heat pump is competitive. Connection works, demand charges, utilisation and capital cost may matter as much as the energy price. A machine that runs only a few hours per week may have a very different result from one serving a steady base load.
Model at least three operating cases: normal production, reduced production and a high-demand or cold-source condition. Include the cost of backup heat during source outages and the value or cost of production downtime during tie-in. Thermal storage and flexible operation can improve the match between electricity availability and process demand, but storage also adds capital, space, heat loss and controls.
Do not present a universal installation cost, payback period, grid-upgrade cost or standard connection time. The cited IEA sources do not establish those figures; they depend on plant, country, utility and project design. Obtain a site-specific electrical study, process integration design and financial model.
Common installation problems and corrective actions
The heat pump is specified before the grid study
Symptom: The selected capacity exceeds the available import limit or triggers an unexpected transformer and network upgrade.
Correction: Recalculate coincident peak demand, ask the utility for a formal connection assessment and test staged capacity, storage or hybrid operation. Do not assume a smaller compressor automatically solves the network constraint; auxiliaries and operating hours still matter.
The source is hot only during ideal conditions
Symptom: Measured performance collapses during cleaning, low production or seasonal operation.
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Correction: Use a representative time series, add an intermediate loop or backup source, and size the heat pump for dependable rather than theoretical availability.
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The required steam pressure is treated as a temperature number
Symptom: A heat pump can produce heat near the target temperature but cannot maintain the pressure, flow or response required by the process.
Correction: Specify steam pressure, mass flow, quality, ramp rate and condensate conditions at the user. Consider heat-pump preheating with an electric boiler or existing boiler for final steam production.
Controls ignore production changes
Symptom: Pressure swings, nuisance trips or inefficient cycling occur when batches change or other plant loads start.
Correction: Coordinate the heat pump, storage, boilers, pumps and process-control system around explicit priorities: process protection, grid import limit, storage state of charge and energy cost.
The project schedule omits utility and outage work
Symptom: Mechanical installation is complete but the electrical connection, protection changes or production tie-in is not ready.
Correction: Put utility studies, permits, long-lead switchgear, factory acceptance tests and the production outage into one integrated schedule. The possible multi-year connection period identified by the IEA should be treated as an early planning risk, not a last-minute procurement detail.
Questions to resolve before approval
- What measured source temperature and flow are available at the minimum, average and peak production states?
- What exact temperature, pressure, flow and ramp rate does every process user require?
- What is the heat pump’s electrical demand at the coldest source and highest sink condition?
- Can the existing connection and transformers support that demand concurrently with production?
- What utility works, permits and protection changes are required, and when can they be completed?
- What is the fallback heat source during a compressor trip, source outage or grid constraint?
- Can storage or schedule changes shift load without compromising product quality?
- Which alternative—heat pump, electric boiler, hybrid or continued boiler operation—delivers the required duty with acceptable risk?
Industrial heat pumps are neither a universal boiler replacement nor an experimental concept. They are commercially available for many low- and medium-temperature duties, and real steam applications exist. Feasibility rests on the match between source profile, temperature lift, process pressure, electrical connection and integration schedule; those variables must be proven with plant data before investment.
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