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A cement plant can capture carbon dioxide (CO₂) by separating it from kiln exhaust or by keeping the CO₂ released from heated limestone apart from other gases. The best-established cement-sector approach described by the International Energy Agency (IEA) is post-combustion chemical absorption: exhaust passes through a solvent that absorbs CO₂, then heat releases the CO₂ so the solvent can be reused. The captured gas still needs conditioning and transport to a use or storage site.
Why cement plants need more than fuel-emissions controls
Cement production releases CO₂ from two sources. Burning fuel supplies heat to the kiln, while calcination—the chemical decomposition of limestone as it is heated—releases CO₂ as part of making clinker, the main intermediate in cement. Improving fuel efficiency or changing fuels can reduce combustion emissions, but it does not by itself eliminate the CO₂ from limestone chemistry. Capture systems therefore need to handle either a mixed kiln exhaust stream or process CO₂ isolated during limestone heating. The IEA’s CCUS overview describes these distinctions and the main capture routes.
A capture rate is not the same as a plant-wide emissions reduction. The rate describes how much CO₂ a particular capture configuration separates within its stated system boundary; remaining emissions can come from uncaptured process gas, fuel and electricity use, and other parts of production. Nor does capture alone mean permanent avoidance: the destination and fate of the CO₂ matter.
How post-combustion amine capture works
- Clean and route the exhaust. Kiln flue gas is treated as needed and sent to an absorber. Solvent performance can be affected by sulfur and nitrogen oxides, so cleanup requirements depend on the gas and system design.
- Absorb the CO₂. In the absorber, exhaust contacts an amine solvent, commonly monoethanolamine (MEA). The solvent takes up CO₂ while much of the other gas continues through the system.
- Release concentrated CO₂. CO₂-rich solvent flows to a desorber, where heat releases the CO₂. The regenerated solvent returns to the absorber for reuse.
- Condition and send the captured gas onward. The released stream is further purified or conditioned to meet the requirements of its transport and destination.
This is often described as a retrofit-style approach because the capture train can be added to the end of production, but it is not a plug-in unit: it requires absorbers, solvent circulation, heat supply, electricity and integration with the plant. The Global Cement and Concrete Association (GCCA) overview discusses the cement application and its integration needs.
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The IEA reports that cement-specific amine-sorbent trials at Norcem Brevik ran for around 8,000 operating hours and captured 2 kilotonnes of CO₂ in total between 2013 and 2016. These are historical trial results, not an annual output figure or a statement of the plant’s current capture performance. The IEA’s industry innovation-gaps analysis also gives up to 95% capture for chemical-absorption post-combustion as a technology estimate; it should not be read as a guaranteed whole-plant emissions reduction.
What the other capture configurations change
| Configuration | What it does differently | Key integration issue |
|---|---|---|
| Oxy-fuel | Burns fuel in oxygen-rich conditions so exhaust contains less nitrogen and is richer in CO₂. | Requires oxygen production and changes to combustion and flue-gas handling. |
| Calcium looping | Uses CaO to bind CO₂ as CaCO₃, then heats the carbonate to release CO₂ and regenerate CaO. | Requires high-temperature heat; sorbent performance declines over repeated cycles. |
| Direct separation | Indirectly heats limestone so process CO₂ is separated from combustion gases. | Requires a different calciner design and integration with the production line. |
| Membranes or ammonia-based capture | Separate CO₂ through selective membranes or ammonia-based post-combustion chemistry. | The cited overviews do not establish these as commercially proven cement-kiln solutions. |
Oxy-fuel: make the exhaust richer in CO₂
Ordinary combustion uses air, which contains nitrogen that dilutes the flue gas. Oxy-fuel burns fuel in oxygen-rich conditions, reducing nitrogen in the exhaust; after water is removed, a more concentrated CO₂ stream remains for further processing. The plant needs an air separation unit to supply oxygen, as well as heat-recovery and flue-gas-recirculation arrangements. Air leakage and burner and cooler design also affect integration.
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The GCCA distinguishes full oxy-fuel, applied across the pyroprocess, from partial oxy-fuel, applied only to calcination. Its technology overview reports indicative capture-rate ranges of 90–99% for full oxy-fuel and 55–75% for partial oxy-fuel. These are technology ranges, not guaranteed outcomes at an individual plant. The same overview says its integrated equipment configuration would more than double electricity use per tonne of clinker and raise production cost by 40–50%; those are overview figures, not a project-specific estimate. Full oxy-fuel entails greater production-line adaptation, while partial oxy-fuel may allow staged implementation.
Calcium looping: bind CO₂ with a recyclable mineral sorbent
In a carbonator, calcium oxide (CaO) reacts with CO₂ to form calcium carbonate (CaCO₃). The carbonate then moves to a separate calciner, where heat releases concentrated CO₂ and regenerates CaO for another cycle. The GCCA gives a calcination temperature of about 850–950°C. Heat can be supplied directly or indirectly; direct heating commonly uses oxygen-rich combustion to avoid diluting the CO₂ with nitrogen, but that makes oxygen supply an additional energy demand.
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CaO loses capture performance over repeated cycles, so a system needs sorbent replacement and a way to manage spent material. The IEA describes the technology as pilot or pre-commercial in its general overview and notes testing in cement manufacture; that is not evidence of routine commercial deployment across cement plants. See the GCCA calcium-looping overview.
Direct separation: isolate process CO₂ at the calciner
Direct separation changes the calciner so limestone is heated indirectly. The CO₂ released by limestone decomposition is kept separate from combustion gases, reducing the need to separate it from a mixed flue gas. The IEA cites the LEILAC pilot at the HeidelbergCement plant in Lixhe, Belgium, as an example of the technology being tested; that example does not establish its current operating status or performance at other plants.
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Membranes and ammonia: options with maturity limits
Membranes selectively pass CO₂ while retaining other gases. The IEA’s overview characterizes flue-gas membrane treatment as under development; commercial membranes used for syngas or biogas do not by themselves demonstrate equivalent readiness for cement-kiln exhaust. Ammonia-based post-combustion capture has been piloted in other industrial and power contexts, but the GCCA says commercial-scale use under cement-flue-gas conditions remains unproven. These are emerging possibilities, not established substitutes for amine systems at cement plants.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.What happens to CO₂ after capture
Capture is one link in a chain. The separated gas needs purification or conditioning, compression as required, and transport to a destination. Large-volume transport options include pipelines and ships; trucks and rail can serve smaller volumes, generally at higher cost per tonne. The IEA emphasizes that safe, reliable CO₂ transport infrastructure is essential for deployment in its CCUS overview.
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At the destination, CO₂ may be used in a product or injected into geological formations for storage. Utilization is not automatically permanent: the climate outcome depends on the product, how long the carbon remains bound, and what emissions the use displaces. Geological storage is intended to keep the CO₂ isolated over the long term, subject to site selection, monitoring and storage-chain performance. A project’s claimed emissions benefit should therefore specify whether captured CO₂ is stored or used, and account for the full chain rather than equating capture with permanent storage.
What determines a plant’s energy use and cost
Capture equipment consumes energy in addition to the energy used to make clinker. For amine chemical absorption, the IEA’s 2018 industry analysis estimates additional thermal demand of 1–3.5 GJ per tonne of clinker and electricity demand of 50–90 kWh per tonne of clinker. These are source-reported estimates, not universal plant values or 2026 measurements; actual requirements depend on the plant, exhaust and system design. Solvent regeneration is a major heat demand. Oxy-fuel and direct-heated calcium looping add the energy burden of oxygen production, while all configurations need electricity for equipment and CO₂ handling.
Cost figures also depend on scope and date. In its 2025 Cement and Concrete Breakthrough Agenda report, the IEA estimates that early commercial near-zero-emissions cement plants using CCS have production costs 75–150% higher than conventional plants, varying by region. The estimate uses 2024 energy prices, energy intensities and fuel mixes and excludes explicit policy supports. It is a production-cost premium for near-zero-emissions plants, not a capture-only price or a quote for any one facility.
How to compare capture options for a specific plant
No single capture rate or technology label is enough to select a system. A plant assessment needs to establish:
Do these 3 things before closing this tab:
1Repair Windows errors before they cause bigger problems2Scan for outdated or missing drivers - takes under a minute3Clear out junk files and repair common Windows errors- Which CO₂ stream is targeted: mixed kiln flue gas, process CO₂ from calcination, or both.
- What the performance figure covers: capture rate, residual process and combustion emissions, and any additional emissions from supplying heat, electricity and oxygen.
- How the system fits the existing line: equipment changes, available space, outage and tie-in requirements, and the consequences of full versus staged integration.
- What the energy and materials demand: heat and electricity supply, oxygen production where relevant, gas cleanup, solvent or sorbent replacement, and waste management.
- Whether the CO₂ chain exists: purification specifications, transport capacity, destination availability and the distinction between use and durable storage.
- Which local conditions shape economics: plant design and gas composition, regional energy prices, capital costs and policy support.
The available technology overviews do not provide a universal engineering design or current site-by-site cost. A credible project comparison therefore needs plant-specific engineering and a clearly stated boundary for both emissions and cost.
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