The numbers are stark. Atmospheric CO2 levels have risen from roughly 280 parts per million before the Industrial Revolution to over 420 ppm today. Global temperatures are climbing. And while the world has made impressive strides in renewable energy, solar and wind alone cannot solve the problem—especially for industries like cement, steel, and chemicals that emit carbon as an inherent part of their processes.
Enter carbon capture. For decades, it was dismissed as too expensive, too energy-intensive, or simply a distraction from the real work of cutting emissions. That narrative has shifted. Since Norway's Sleipner project began storing CO2 beneath the North Sea in 1996, the technology has matured from experimental to operational. Today, over 40 commercial facilities capture more than 45 million tonnes of CO2 annually—and that number is growing.
Here are seven ways carbon capture is making a tangible difference right now.
Most large-scale carbon capture today happens at the smokestack. In post-combustion capture, flue gas from a power plant or factory passes through a solvent—typically an amine-based solution—that absorbs CO2. The solvent is then heated to release a concentrated stream of CO2, which can be compressed and transported for storage or use. The cleaned flue gas is released to the atmosphere with significantly less CO2.
Saskatchewan's Boundary Dam power station is the proof of concept. Since 2014, this coal-fired plant has captured roughly 1 million tonnes of CO2 per year using post-combustion technology. The captured CO2 is used for enhanced oil recovery in nearby fields, with a portion stored permanently in deep geological formations.
The project hasn't been without challenges—early years saw technical issues and downtime—but it demonstrated that commercial-scale capture at a power plant is achievable. The lessons learned have informed subsequent designs worldwide.
The catch is energy. Capturing CO2 requires substantial heat and electricity, which can reduce a plant's net output by 20–30%—what engineers call the "energy penalty." Costs have fallen but remain significant: roughly $40–$80 per tonne of CO2 captured at coal plants, according to the International Energy Agency. That's a hard sell without policy support or a price on carbon.
Key Takeaway: Post-combustion capture is the most mature carbon capture technology, proven at commercial scale for over a decade. Its main barrier is cost and energy penalty, not technical feasibility.
Post-combustion capture works on concentrated streams of CO2—think exhaust pipes and smokestacks. But roughly half of global emissions come from diffuse, distributed sources like cars, planes, and heating systems. You can't bolt a capture unit onto a tailpipe. Direct air capture (DAC) solves this by pulling CO2 directly from ambient air, regardless of where the emissions originated.
DAC systems use giant fans to draw air over chemical sorbents that bind with CO2. When the sorbent is saturated, it's heated or subjected to a vacuum to release pure CO2. The chemistry works; the challenge is that atmospheric CO2 is dilute—just 420 parts per million—so processing enormous volumes of air requires significant energy.
In 2021, Climeworks switched on Orca, the world's largest DAC facility, in Hellisheiði, Iceland. Orca captures 4,000 tonnes of CO2 per year—a drop in the bucket compared to global emissions, but a critical scale-up demonstration. What makes Orca special is what happens to the captured CO2: it's dissolved in water and injected into basalt rock, where it mineralizes into solid carbonate within two years. The CO2 isn't just stored; it becomes stone.
DAC remains pricey. Estimates range from $250 to $600 per tonne, according to the National Academies of Sciences, Engineering, and Medicine. The U.S. Department of Energy has set a target to drive costs below $100 per tonne by 2035 through its Carbon Negative Shot program. Whether that's achievable depends on scaling manufacturing, improving sorbent materials, and securing cheap renewable energy to power the process.
Key Takeaway: Direct air capture is the only technology that can address historical and diffuse emissions. It's early-stage and expensive, but costs are projected to fall dramatically as deployment scales.
Not all captured CO2 needs to go underground. Carbon capture utilization and storage (CCUS) treats CO2 as a feedstock rather than a waste product. This approach creates an economic incentive: if captured CO2 can be sold, the cost of capture becomes more palatable.
The list of potential CO2-derived products is growing. CO2 can be combined with hydrogen to produce synthetic fuels for aviation and shipping—sectors that are notoriously hard to electrify. It can be converted into methanol, a versatile chemical used in plastics, adhesives, and solvents. And in the construction sector, CO2 can be mineralized into aggregates for concrete, effectively locking carbon into buildings and roads that last for decades.
One notable example is CarbonCure, a Canadian company that injects captured CO2 into wet concrete during mixing. The CO2 reacts with calcium ions to form calcium carbonate, which strengthens the concrete while permanently storing the carbon. Over 500 concrete plants worldwide now use the technology.
The economics are improving but remain challenging. Converting CO2 into products requires energy and hydrogen, which adds cost. A 2019 analysis in Joule estimated that CO2-derived fuels could become competitive if carbon prices reached $100–$200 per tonne and renewable hydrogen costs fell. The market for CO2-based products is still nascent, but it offers a pathway where carbon capture pays for itself rather than purely costing money.
Key Takeaway: CCUS transforms carbon capture from a cost center into a potential revenue stream. The market is young, but the range of possible products—fuels, chemicals, building materials—is broad.
Bioenergy with carbon capture and storage (BECCS) is one of the few technologies that can deliver negative emissions—actually removing CO2 from the atmosphere. Here's the logic: plants absorb CO2 as they grow. When you burn that biomass for energy, you release the CO2 back. But if you capture those emissions and store them underground, you've effectively pulled carbon from the atmosphere and locked it away.
The result is a net reduction in atmospheric CO2, not just a slowdown in emissions growth.
The Intergovernmental Panel on Climate Change (IPCC) has consistently highlighted BECCS as a key negative emissions technology in scenarios that limit warming to 1.5°C. The IEA's Net Zero by 2050 roadmap projects that BECCS could deliver around 1.2 billion tonnes of negative emissions annually by mid-century.
Commercial-scale BECCS is still in early stages. The most prominent example is the Illinois Industrial CCS project, which captures CO2 from an ethanol plant—a bioenergy facility—and stores it in a deep saline aquifer. Since 2017, it has stored over 5 million tonnes of CO2.
In the UK, the Drax power station, which converted from coal to biomass pellets, has run pilot BECCS trials and plans full-scale deployment. The Stockholm Exergi facility in Sweden is building a BECCS plant designed to capture 800,000 tonnes of CO2 annually from a biomass combined heat and power plant.
Key Takeaway: BECCS is the most mature negative emissions technology available. It's not a silver bullet—it requires sustainable biomass sourcing and significant land use—but it's essential in most credible climate scenarios.
Enhanced oil recovery (EOR) has been used for decades to extract more oil from aging reservoirs. The technique involves injecting CO2 into an oil field, where it mixes with the oil, reduces its viscosity, and helps push it toward production wells. About 5% of U.S. oil production currently uses CO2-EOR.
Here's the twist: much of the injected CO2 remains trapped underground after the oil is extracted. This means EOR can double as a carbon storage mechanism—though the oil produced does generate new emissions when burned.
The Petra Nova project in Texas was the poster child for this approach. Completed in 2017 at a coal-fired power plant, it captured about 1.6 million tonnes of CO2 annually and piped it to the West Ranch oil field for EOR. The project was mothballed in 2020 when oil prices crashed during the pandemic—a reminder of the economic vulnerability of linking carbon capture to oil markets. It was reactivated in late 2023 with improved economics.
Other notable EOR projects include the Weyburn-Midale field in Canada, which has stored over 40 million tonnes of CO2 since 2000, and the Gorgon project in Australia, which injects CO2 from natural gas processing into a saline aquifer beneath Barrow Island.
EOR is controversial in climate circles. Critics argue that using captured CO2 to extract more oil perpetuates fossil fuel dependence and that the emissions from burning that oil may offset the storage benefit. Proponents counter that EOR provides the revenue stream that makes carbon capture economically viable and that the net result—when accounting for both storage and avoided emissions—is still positive in many cases.
The science depends on the specific project. A 2020 study in Nature Climate Change found that the lifecycle emissions of CO2-EOR vary widely based on factors like the CO2 source, the oil-to-CO2 ratio, and how much CO2 remains stored. Well-designed EOR projects can be net-negative; poorly designed ones may not be.
Key Takeaway: CO2-EOR is a proven way to store carbon at scale, but its climate benefits depend on project specifics. It's best viewed as a transitional strategy that can fund infrastructure for dedicated geological storage.
Capture is only half the equation. The CO2 has to go somewhere permanent. The most common storage sites are:
Once injected, CO2 is trapped through four mechanisms that increase in permanence over time:
The final stage, mineralization, can take decades to centuries depending on the geology. In basalt formations like those in Iceland, it happens in under two years.
No project better demonstrates the safety of geological storage than Sleipner. Since 1996, this Norwegian natural gas operation has stripped CO2 from extracted gas and injected it into the Utsira Formation, a saline aquifer beneath the North Sea. Over 20 million tonnes have been stored so far—equivalent to taking 4 million cars off the road for a year.
Extensive monitoring using seismic surveys and well data has confirmed the CO2 plume is behaving as predicted. There have been no leaks, no induced seismicity, and no impact on the marine environment. Sleipner was originally driven by Norway's carbon tax, which made storage cheaper than paying the tax. It remains the gold standard for demonstrating that geological storage works at scale, safely, and permanently.
Key Takeaway: Geological storage is not a theoretical concept—it has been operating safely for over 25 years at Sleipner. The trapping mechanisms are well-understood, and monitoring confirms that properly selected sites retain CO2 for geological timescales.
Carbon capture has always faced a chicken-and-egg problem: high costs deter investment, and low investment keeps costs high. Policy can break that cycle. The most significant U.S. mechanism is the 45Q tax credit, which provides up to $85 per tonne for CO2 stored permanently and $60 per tonne for CO2 used in EOR. When combined with other incentives, this can make many projects economically viable.
The Inflation Reduction Act of 2022 extended and expanded 45Q, increasing the credit's value and extending the deadline for commencing construction to 2033. This has triggered a wave of project announcements—over 100 new carbon capture projects have been proposed in the U.S. since the IRA's passage.
The momentum is not limited to the U.S. The Global CCS Institute reports that as of 2023, over 40 commercial CCS facilities are in operation or under construction worldwide, with a combined capture capacity exceeding 100 million tonnes per year. The pipeline of projects in development is even larger—over 200 facilities are at various stages of planning.
Canada, Norway, the Netherlands, and Australia have all made significant investments. The UK has announced a £20 billion commitment to carbon capture over the next two decades. China is developing several large-scale projects despite being a late entry into the field.
The technology itself is also evolving. First-generation capture systems use amine solvents that require significant energy to regenerate. Researchers are developing:
These advances could reduce the energy penalty and cost of capture by 30–50% over the next decade.
Key Takeaway: Policy support and technological innovation are working in tandem to scale carbon capture. Costs are falling, project pipelines are expanding, and next-generation materials promise further improvements.
Carbon capture involves separating CO2 from emission sources (like power plants or industrial facilities) or directly from ambient air, then compressing and transporting it to a storage site (typically deep underground) or using it as a feedstock for products. The most common methods use chemical solvents, solid sorbents, or membranes to separate CO2 from other gases.
Yes, when done properly. CO2 is stored in geological formations that have trapped gases and fluids for millions of years. Multiple trapping mechanisms—structural, residual, solubility, and mineral—ensure the CO2 remains underground. The Sleipner project has stored over 20 million tonnes since 1996 without leakage. Sites are carefully selected and monitored using seismic imaging, pressure sensors, and groundwater sampling.
Carbon capture is an essential complement to emissions reductions, not a substitute. The IEA's Net Zero by 2050 scenario requires capturing 7.6 billion tonnes of CO2 annually by mid-century. It's particularly critical for hard-to-abate sectors like cement, steel, and chemicals, where process emissions cannot be eliminated through electrification alone.
Costs vary widely by technology. Post-combustion capture at power plants costs roughly $40–$80 per tonne of CO2. Direct air capture is more expensive, at $250–$600 per tonne, though costs are expected to fall to $100–$150 by 2050. Policy incentives like the U.S. 45Q tax credit (up to $85 per tonne) can offset a significant portion of these costs.
CCS (carbon capture and storage) involves capturing CO2 and storing it permanently underground. CCUS (carbon capture utilization and storage) includes using the captured CO2 as a feedstock for products like synthetic fuels, chemicals, or building materials. CCUS can create economic value from captured CO2 but may not provide permanent storage if the products eventually release the CO2.
Yes. Sleipner (Norway) has stored over 20 million tonnes since 1996. Boundary Dam (Canada) captures 1 million tonnes annually from a coal plant. Orca (Iceland) captures CO2 from air and mineralizes it in basalt. Gorgon (Australia) is one of the world's largest CCS projects, targeting 4 million tonnes per year.
The main challenges are cost, energy penalty, and scale. Current technology consumes significant energy, reducing net efficiency. Costs, while falling, remain higher than most companies will absorb without policy support. And global capture capacity of 45 million tonnes annually is far short of the 1.2 billion tonnes needed by 2050.
Yes, and this integration is increasingly important. Direct air capture facilities can be powered entirely by renewable energy. BECCS combines bioenergy—a renewable source—with carbon capture. Some industrial processes, like cement production, generate CO2 regardless of their energy source, making capture essential even in a fully renewable grid.
Current operational capacity is about 45 million tonnes per year. The IEA's Net Zero by 2050 scenario requires CCS to contribute 1.2 billion tonnes annually by 2050, with total carbon capture (including DAC and BECCS) reaching 7.6 billion tonnes. The global geological storage capacity is estimated at thousands of gigatonnes—far more than needed.
Carbon capture plays three roles: reducing emissions from existing fossil infrastructure, enabling negative emissions when combined with bioenergy or direct air capture, and addressing process emissions from industries like cement and steel that cannot be eliminated otherwise. It's not an alternative to renewables—it's a necessary complement.
Carbon capture has moved from laboratory curiosity to operational reality. The Sleipner project has stored CO2 for over 25 years without incident. Boundary Dam has proven post-combustion capture at commercial scale. Orca has demonstrated that direct air capture can work in the real world. And the policy landscape has shifted dramatically, with incentives like the 45Q tax credit spurring a wave of new projects.
But carbon capture is not a magic bullet. It cannot—and should not—replace the fundamental work of reducing emissions through renewable energy, energy efficiency, and electrification. The IEA is clear: carbon capture is a complement, not a substitute, for emission cuts. Every tonne of CO2 that doesn't need to be produced is a tonne that doesn't need to be captured.
What carbon capture offers is a bridge: a way to clean up the industries we can't easily electrify, a mechanism to remove the CO2 we've already emitted, and a tool to make the transition to net-zero both faster and more affordable.
The technology is ready. The economics are improving. What's needed now is continued policy support, sustained investment, and public awareness. The projects being built today will determine whether carbon capture reaches the scale the climate crisis demands.
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