Carbon capture technology has been deployed commercially for more than 50 years, yet it captures a vanishingly small fraction of global emissions. In 2024, the world emitted 37.4 billion tonnes of CO2 from fossil fuels alone[s]. All operational carbon capture facilities combined removed roughly 50 million tonnes[s], about 0.13% of that total. This gap is not a failure of ambition or funding alone. It reflects structural constraints in how the technology works, what it costs, and why those costs have not fallen the way solar and wind costs have.
How Carbon Capture Technology Works
Carbon capture technology intercepts CO2 before it reaches the atmosphere (or pulls it from the air directly) and stores it underground. The most common approach uses chemical solvents, typically aminesChemical compounds used as solvents in carbon capture systems to selectively bind and release CO2 molecules through heating and cooling cycles., that bind to CO2 molecules.
The process works in two stages. First, exhaust gases from a power plant or factory pass through an absorption column where the solvent selectively removes CO2[s]. The CO2-laden solvent then moves to a second column where it is heated. Heat breaks the chemical bond, releasing pure CO2 for compression and storage, while the regenerated solvent cycles back to capture more[s].
This regeneration step is the bottleneck. Breaking those chemical bonds requires substantial energy input, posing an economic and environmental challenge[s]. A coal plant fitted with carbon capture technology can require about 25% more fuel to generate the same electricity as one without it[s].
What It Costs
Carbon capture technology costs vary enormously depending on the CO2 source. Capturing CO2 from concentrated streams, such as natural gas processing or ethanol production, costs $15 to $25 per tonne[s]. Capturing from dilute streams, such as power plant exhaust or cement kilns, costs $40 to $120 per tonne[s].
Direct air captureTechnology that pulls CO2 directly from ambient air for storage, requiring massive energy input due to low atmospheric CO2 concentrations., which pulls CO2 from ambient air at roughly 0.04% concentration, costs far more: $200 to $600 per tonne[s]. The physics are unforgiving: lower CO2 concentrations mean more air must be processed and more energy consumed per tonne captured.
Transport and storage add further costs. Pipeline transport in the United States runs $2 to $14 per tonne depending on distance, while storage costs depend on geology. In favorable formations, storage can cost under $10 per tonne[s].
Why Costs Have Not Fallen Like Solar
Solar panel costs dropped 23% every time global installed capacity doubled[s]. Carbon capture technology has shown experience rates of just 2% to 7%[s]. This dramatic difference stems from structural factors.
First, carbon capture systems are complex and must be customized to each facility. Each power plant, cement kiln, or refinery has different exhaust compositions, temperatures, and operating conditions[s]. This prevents the mass manufacturing that drove solar costs down.
Second, CCS cannot benefit from the economies of scale that come from producing millions of identical units[s]. Manufacturing remains bespoke: individual sites are fitted with their own capture equipment, and no mass manufacturing takes place[s].
The Boundary Dam Warning
The Boundary Dam 3 project in Saskatchewan offers a cautionary example. More than CAD 1 billion was spent retrofitting this coal plant with carbon capture technology[s]. Proponents promised 90% capture rates. After nine years of operation, the actual long-term capture rate was 57%[s].
The project never reached its annual target of capturing one million tonnes[s]. Capture was limited by both technical issues and fluctuating demand for CO2 from enhanced oil recoveryProcess of injecting captured CO2 into oil fields to extract additional petroleum that conventional drilling cannot reach. operations[s].
In 2024, Capital Power cancelled a $2.4 billion carbon capture project at its Genesee plant. The CEO’s explanation was blunt: “Fundamentally, the economics just don’t work”[s].
The Scale Problem
The gap between what exists and what climate models require is immense. Current global capacity stands at roughly 50 million tonnes per year[s]. Net zero scenarios require capturing around 1 billion tonnes by 2030[s], a 20-fold increase in five years.
Permanent, engineered carbon dioxide removal—direct air capture and similar atmospheric technologies, distinct from the point-source capture above—currently accounts for about one-millionth of CO2 emitted from fossil fuels[s]. If global emissions remain at current levels, the remaining carbon budget to limit warming to 1.5°C will be exhausted in roughly six years[s].
Where It Might Work
Carbon capture technology makes the most sense in sectors with no alternatives. Cement production generates two-thirds of its emissions from chemical reactions when heating limestone, not from burning fuel[s]. You cannot electrify chemistry. The largest cement plant carbon capture project, in Norway, aims to capture 400,000 tonnes annually[s].
The Stratos facility in Texas, designed to capture 500,000 tonnes of CO2 per year from ambient air[s], represents the cutting edge of direct air capture. Companies including JP Morgan and Palo Alto Networks have purchased removal credits[s]. But even this flagship project would remove less than 0.002% of annual global emissions.
The 45Q tax credit now provides $85 per tonne for point-source capture and $180 per tonne for direct air capture[s]. These subsidies close much of the cost gap, but they do not address the fundamental scaling challenges.
Carbon Capture Technology Mechanisms
Carbon capture technology encompasses three primary approaches: post-combustion captureMethod of capturing CO2 from exhaust gases after fuel combustion, typically using chemical solvents in absorption columns. from flue gases, pre-combustion capture via gasification, and direct air captureTechnology that pulls CO2 directly from ambient air for storage, requiring massive energy input due to low atmospheric CO2 concentrations. (DAC) from ambient air. Post-combustion capture dominates current deployments due to its retrofittability to existing infrastructure.
The most commercially mature post-combustion approach uses amine-based chemical absorption. Flue gas enters an absorption column where aqueous amine solvents, typically monoethanolamine (MEA), selectively bind CO2 through carbamate formation[s]. The CO2-rich solvent proceeds to a stripper column where thermal energy reverses the reaction, liberating concentrated CO2 for compression while regenerating the solvent[s].
MEA remains the dominant first-generation solvent due to high selectivity, rapid reaction kinetics, and low cost. However, it degrades in the presence of oxygen and SOx, requiring flue gas pretreatment[s]. Second-generation solvents, including sterically hindered aminesChemical compounds used as solvents in carbon capture systems to selectively bind and release CO2 molecules through heating and cooling cycles. and amino acid blends, offer lower regeneration temperatures and better degradation resistance, but at higher cost and reduced absorption rates[s].
The thermodynamic penalty is significant. Regeneration requires 3.5 to 4.0 GJ of thermal energy per tonne of CO2 for conventional MEA systems. A coal plant with carbon capture technology requires approximately 25% more fuel to produce equivalent net electrical output[s].
Cost Structure Analysis
Carbon capture technology costs scale inversely with CO2 partial pressure. Capture from high-purity streams (natural gas processing, ammonia production) costs $15 to $25/tCO2[s]. Capture from dilute streams (power generation at 3-15% CO2, cement at 14-33% CO2) costs $40 to $120/tCO2[s].
Regional cost modeling for the northeastern and midwestern United States found total CCS costs of $52 to $60/tCO2 for coal-sourced emissions and $80 to $90/tCO2 for natural gas plants[s]. Component analysis attributes $47/tCO2 to capture at coal plants and $76/tCO2 at natural gas combined-cycle plants[s].
DAC operates against thermodynamics: ambient CO2 concentration of approximately 420 ppm requires processing roughly 2,500 tonnes of air per tonne of CO2 captured. Current DAC costs range from $200 to $600/tCO2[s], with theoretical lower bounds around $100/tCO2 dependent on low-cost renewable energy and process optimization.
Experience Curve Constraints
Carbon capture technology exhibits experience rates of 2% to 7% compared to 23% for solar PV[s]. This disparity reflects fundamental differences in technological architecture.
CCS systems exhibit high design complexity with multiple interacting subsystems: flue gas pretreatment, absorption columns, regeneration systems, compression trains, and storage infrastructure[s]. Each installation requires customization to specific exhaust compositions, geological conditions, and existing plant configurations[s].
This precludes mass manufacturing. Solar PV benefits from producing millions of identical modules on automated production lines. CCS manufacturing remains bespoke, with individual sites fitted with custom capture equipment[s]. The relative lack of deployment means many technologies remain at an early stage of commercialization, at a high point on the cost curve[s].
Cost of capture in the power sector has fallen 35% from the first to second large-scale facility[s], but the small number of deployments provides limited data for projecting future trajectories.
Operational Performance Data
The Boundary Dam 3 project provides the most extensive operational dataset. After CAD 1 billion in retrofit costs[s], the facility achieved a long-term capture rate of 57%, not the 90% design specification[s].
Analysis reveals two primary limitations. The carbon capture portion operated during only 80% of plant operating hours. When operational, it processed only 73% of flue gas flow on average[s]. These compounding factors help explain the gap between design and actual capture rates.
Shell’s Quest project in Alberta achieved 77% capture rate, below its 90% design target[s]. Capital Power’s cancellation of a $2.4 billion project cited economics as the fundamental barrier[s].
Scale Requirements vs. Deployment Reality
Global operational capacity reached 50 Mt/year by Q1 2025[s]. The Global CCS Institute tracks 70 operational projects with combined capacity of 61 Mtpa[s]. Pipeline projections indicate 430 Mt/year by 2030[s].
Net zero pathways require approximately 1 Gt/year capture capacity by 2030[s]. The pipeline falls short by a factor of 2.3x. Against 2024 fossil emissions of 37.4 GtCO2[s], even the optimistic 2030 projection would capture 1.1% of annual emissions.
Permanent, engineered atmospheric carbon dioxide removal (DAC, BECCS, and similar, distinct from the point-source CCS capacity discussed above) currently represents approximately one-millionth of annual fossil emissions[s]. The remaining carbon budget for 1.5°C (50% probability) is approximately six years at current emission rates[s].
Economic Incentives and Deployment Outlook
U.S. 45Q tax credits provide $85/tCO2 for point-source capture and $180/tCO2 for DAC with geologic storage[s]. These subsidies approach or exceed capture costs for concentrated streams but cover only 15-40% of DAC costs.
The Stratos DAC facility in Texas targets 500,000 tCO2/year[s]. Corporate offtakers including JP Morgan (50,000 tonnes) and Palo Alto Networks (10,000 tonnes) have committed to credits[s]. At full capacity, Stratos would remove 0.0013% of annual global fossil emissions.
Carbon capture technology likely retains a role in hard-to-abate sectors. Cement production, where process emissions from limestone calcination constitute two-thirds of total emissions, has limited electrification pathways[s]. The Brevik cement plant carbon capture project in Norway, targeting 400,000 tCO2/year[s], represents a test case for industrial applicability.
Eighty percent of capture capacity expected by 2030 is concentrated in North America and Europe[s], where policy support and geological storage availability align. Global deployment will require comparable policy frameworks and storage characterization in other regions.
