Carbon capture in power generation is transitioning from isolated demonstration projects to a system-level decarbonization lever with material economic implications. While deployment remains limited relative to variable renewables, policy support, technology improvements, and rising carbon costs are pushing carbon capture from conceptual discussions into serious portfolio consideration for certain power systems.
Quantitatively, post-combustion capture systems typically remove 85–95% of CO₂ from flue gas streams. For a 500 MW coal or gas-fired power plant, this translates into the capture of approximately 2–3 million tonnes of CO₂ per year, depending on fuel type and operating profile. At scale, even a modest fleet of retrofitted plants can deliver system-level emissions reductions comparable to large renewable buildouts.
Cost structures are evolving. The levelized cost of CO₂ capture for power generation has declined from historical levels exceeding $90–120 per tonne to ranges increasingly cited between $50–80 per tonne for optimized, large-scale applications. While still material, these costs are increasingly competitive when compared against the system costs of replacing firm thermal capacity with variable renewables plus storage and transmission expansion.
Energy penalties remain a central constraint. Capture systems typically reduce net plant output by 15–25% due to parasitic load. This means that a 500 MW plant may effectively deliver only 375–425 MW post-retrofit, requiring either higher fuel input or additional capacity to maintain system contribution. This reduces thermal efficiency and increases fuel costs, which must be incorporated into dispatch and planning models.
CO₂ transport and storage infrastructure is a gating factor. The economics of capture improve significantly when plants are located near suitable geological storage or existing CO₂ pipeline networks. Transport costs can range from $5–20 per tonne depending on distance, while storage costs vary by geology but often fall in the $5–15 per tonne range. Integrated capture-transport-storage systems therefore benefit from clustering and shared infrastructure.
From a system planning perspective, carbon capture preserves firm capacity while reducing emissions. This is a key advantage relative to retire-and-replace strategies. In systems facing reliability constraints, retrofitting existing thermal assets with capture may be economically and operationally preferable to building large volumes of variable renewables plus long-duration storage.
Policy frameworks materially influence economics. Carbon pricing, emissions performance standards, and tax credits directly affect capture project viability. Where carbon prices exceed $70–100 per tonne or where long-term policy certainty exists, capture projects become significantly more competitive. This creates regional divergence in adoption.
Financial modeling increasingly treats carbon capture assets as hybrid investments, combining characteristics of conventional generation and environmental compliance infrastructure. Revenue stability depends on both energy market revenues and policy-driven carbon incentives. This increases sensitivity to regulatory risk but also creates opportunities for stable, long-duration returns in supportive jurisdictions. Strategically, carbon capture is unlikely to be a universal solution, but it will play a targeted role in power systems where firm capacity is scarce, fuel infrastructure is established, and storage resources are accessible. Its system-level value lies in preserving reliability while materially reducing emissions, making it a pragmatic component of certain decarbonization pathways.
