Trend analysis: CO2 utilization pathways (mineralization, fuels, chemicals) — where the value pools are (and who captures them)

Carbon capture and utilization (CCU) has long occupied an uncomfortable middle ground between climate solution and industrial distraction. Critics argue it extends fossil fuel infrastructure; proponents counter that certain industrial emissions are unavoidable and converting CO2 into durable products or fuels creates genuine economic value. The data now emerging from the Asia-Pacific region, where the largest CCU projects are being built, suggests the answer depends entirely on which utilization pathway you examine. Mineralization into building materials is demonstrating durable economics with minimal subsidy dependence. E-fuels remain stubbornly expensive but attract enormous policy-driven capital. Chemical synthesis occupies a volatile middle ground where feedstock costs and carbon pricing determine viability. Understanding where value pools concentrate across these three pathways is essential for product teams, investors, and policymakers allocating resources in the carbon management economy.

Why It Matters

Global CO2 utilization capacity reached approximately 230 million tonnes per year in 2025, with the Asia-Pacific region accounting for 45% of new project announcements. China alone has committed to 15 major CCU demonstration projects under its 14th Five-Year Plan, spanning mineralization, methanol synthesis, and enhanced oil recovery. Japan's Green Innovation Fund has allocated JPY 2 trillion (approximately USD 14 billion) to carbon recycling technologies, with a particular focus on synthetic fuels for aviation and maritime shipping. South Korea's Carbon Neutrality Act requires industrial emitters to incorporate CCU into decarbonisation plans, creating a captive market for utilization technologies.

The economic stakes are substantial. McKinsey estimates the addressable market for CO2-derived products could reach USD 70-120 billion annually by 2030, but this headline figure obscures dramatic variation across pathways. Mineralized building materials (concrete, aggregite, supplementary cite cite citious materials) represent the largest volume opportunity at 5-10 gigatonnes of potential CO2 uptake, but the value per tonne of CO2 utilized is modest (USD 10-30). Synthetic fuels offer the highest per-tonne value (USD 200-600) but face severe cost competitiveness challenges against fossil alternatives. Chemical intermediates (methanol, ethanol, formic acid, polycarbonates) occupy a middle ground with moderate volumes and potentially attractive margins where carbon pricing creates feedstock cost advantages.

For product and design teams, the critical question is not which pathway is "best" but which creates defensible competitive positions. The answer varies dramatically by geography, regulatory regime, and industrial context. In Asia-Pacific specifically, three factors are reshaping the competitive landscape: the rapid decline in renewable electricity costs (making electrochemical pathways increasingly viable), the emergence of carbon border adjustment mechanisms (CBAM) that penalise carbon-intensive imports into the EU, and the scaling of direct air capture (DAC) that could eventually decouple CO2 supply from point-source emitters.

Key Concepts

Carbon Mineralization permanently converts CO2 into solid carbonates by reacting it with alkaline materials, primarily calcium and magnesium silicates. The resulting products include supplementary cementitious materials (SCMs), aggregates for concrete, and synthetic limestone. The process is thermodynamically favourable (exothermic), meaning it releases energy rather than consuming it, which fundamentally differentiates it from other utilization pathways. Key players include CarbonCure (injecting CO2 into fresh concrete), Solidia Technologies (CO2-cured cement), and Blue Planet Systems (manufacturing synthetic limestone aggregate from captured CO2). The permanence of storage in mineralized products exceeds 10,000 years, satisfying even the most stringent carbon removal criteria.

Electrofuels (E-fuels) combine captured CO2 with green hydrogen (produced via renewable-powered electrolysis) to synthesize liquid hydrocarbons or other energy carriers. The primary products include e-methanol, e-kerosene (for aviation), e-diesel, and e-methane. The process requires substantial electricity input: producing one litre of e-kerosene consumes approximately 25-30 kWh of renewable electricity, compared to near-zero marginal energy for extracting and refining conventional jet fuel. The economics therefore depend almost entirely on renewable electricity costs, electrolyser efficiency, and the price premium that regulators or markets assign to low-carbon fuels.

CO2-to-Chemicals encompasses a broad range of catalytic and electrochemical processes that convert CO2 into chemical feedstocks and intermediates. The most commercially advanced pathway is methanol synthesis via hydrogenation of CO2, already practised at scale by Carbon Recycling International in Iceland and Dalian Institute of Chemical Physics in China. Emerging pathways include electrochemical reduction of CO2 to ethylene (pursued by Twelve and Opus 12), formic acid production (by Liquid Light spin-offs), and polycarbonate synthesis (by Covestro and Econic Technologies). The competitive position of CO2-derived chemicals depends on whether carbon pricing effectively internalises the externality cost of fossil-derived alternatives.

Carbon Contracts for Difference (CCfDs) are government-backed instruments that guarantee a fixed carbon price for CCU project developers, bridging the gap between current market carbon prices and the true cost of CO2 utilization. Germany, the Netherlands, and Japan have pioneered CCfD auctions for industrial decarbonisation, with guaranteed prices ranging from EUR 100-250 per tonne of CO2 avoided. These instruments are increasingly being adopted across Asia-Pacific, with South Korea announcing a CCfD pilot for CCU projects in 2025.

CO2 Utilization KPIs: Benchmark Ranges by Pathway

Metric	Mineralization	E-Fuels	CO2-to-Chemicals
CO2 Utilization Cost (USD/tonne)	15-50	200-600	80-250
Energy Input (kWh/tonne CO2)	50-200	8,000-12,000	2,000-6,000
Product Market Size (USD bn, 2025)	8-12	2-4	5-8
Projected CAGR (2025-2030)	15-25%	35-55%	20-35%
Carbon Permanence	>10,000 years	Months (re-emitted on combustion)	Months to decades
Technology Readiness Level	7-9	5-7	6-8
Subsidy Dependence	Low-Medium	Very High	Medium-High

Where Value Pools Are Concentrating

Mineralization: Volume Play with Defensible Unit Economics

Carbon mineralization into building materials is the only CCU pathway currently approaching subsidy-free economics in multiple geographies. CarbonCure's retrofit technology, which injects CO2 into concrete during mixing, has been deployed at over 700 concrete plants across 30 countries. The company's Asian expansion has been particularly aggressive, with partnerships announced with major ready-mix producers in Japan, Australia, and Southeast Asia. The technology reduces cement content by 5-8% while maintaining or improving compressive strength, generating material cost savings of USD 3-6 per cubic metre that partially offset the CO2 supply cost.

Blue Planet Systems has developed a more capital-intensive but higher-impact approach: manufacturing synthetic limestone aggregate from captured CO2 and industrial waste alkalinity (primarily steel slag and concrete wash water). Each tonne of aggregate sequesters approximately 440 kg of CO2 permanently. The company's first commercial plant in California is operational, and licensing agreements with Taiheiyo Cement in Japan and Holcim for Asia-Pacific deployment signal the pathway's credibility. The aggregate product commands a modest price premium (10-20% above natural aggregate) but generates significant value through carbon credit revenues and reduced disposal costs for industrial waste streams.

Brimstone, backed by USD 55 million from Breakthrough Energy Ventures, is pursuing a more radical approach: producing ordinary Portland cement from calcium silicate rocks rather than limestone, eliminating process CO2 emissions entirely while generating supplementary cementitious materials as co-products. The company's pilot operations demonstrate that the process is cost-competitive with conventional cement at carbon prices above USD 30-50 per tonne, a threshold already exceeded in the EU ETS and approaching in several Asia-Pacific jurisdictions.

E-Fuels: Policy-Driven Demand with Concentrated Value Capture

The e-fuels subsegment exhibits the steepest growth trajectory but the most concentrated value capture. The EU's ReFuelEU Aviation mandate requires 1.2% synthetic fuel blending by 2030 and 35% by 2050, creating a captive demand pool that has driven massive investment. In Asia-Pacific, Japan's Green Growth Strategy targets 10% synthetic fuel blending for aviation by 2030, while South Korea has announced comparable mandates for maritime shipping fuel.

HIF Global, majority-owned by Porsche AG, is constructing the world's largest e-fuels facility in Chile (Haru Oni) and has announced a second plant in Tasmania, Australia. The Australian project leverages the region's exceptional wind resources to produce e-methanol at projected costs of USD 1,200-1,500 per tonne, competitive with current sustainable aviation fuel (SAF) pricing but still 3-4x conventional jet fuel costs. The value capture is heavily concentrated among vertically integrated players who control both renewable electricity generation and fuel synthesis, as electricity represents 60-70% of total production cost.

ENEOS, Japan's largest petroleum refiner, has partnered with Mitsubishi Corporation and the Japan Organization for Metals and Energy Security to develop e-fuel production capacity targeting 300,000 kilolitres annually by 2030. The consortium's strategy exploits Japan's existing fuel distribution infrastructure and regulatory framework to capture margin across the full value chain. For product teams evaluating this space, the key insight is that e-fuel value accrues primarily to those who control low-cost renewable electricity at scale; chemical engineering expertise alone is insufficient.

CO2-to-Chemicals: Selective Opportunities with Volatile Economics

The chemicals pathway presents the most fragmented opportunity landscape. Carbon Recycling International (CRI) operates the George Olah plant in Iceland, producing approximately 4,000 tonnes of methanol annually from geothermal CO2 and renewable hydrogen. CRI has licensed its technology to Shunli in China for a 100,000-tonne methanol plant in Henan province, representing a tenfold scale-up from current operations. The Chinese deployment benefits from significantly lower construction costs and proximity to massive methanol demand centres (China consumes approximately 80 million tonnes of methanol annually, primarily as a chemical feedstock and fuel blend).

Twelve (formerly Opus 12) has developed an electrochemical CO2 reduction platform that converts CO2 and water directly into CO and syngas, which can be further processed into various chemicals and fuels. The company's partnership with the US Air Force for e-jet fuel production has generated significant visibility, and its technology has been selected for demonstration projects in South Korea and Japan. The electrochemical approach bypasses the hydrogen production step, potentially reducing capital costs by 20-30% relative to thermochemical routes, but remains at an earlier stage of commercial deployment.

Covestro's CO2-to-polycarbonate pathway has reached commercial scale, with the company's Dormagen plant in Germany incorporating CO2 as 20% of the feedstock for polyol production since 2016. The technology is being licensed for deployment in China and India, where polycarbonate demand growth of 5-8% annually creates receptive markets. The value proposition is compelling in segments where CO2-derived products can command green premiums: mattress foams, automotive interiors, and sports flooring currently absorb the majority of output.

What's Not Working

Electrolyser Cost and Efficiency Bottlenecks

Every CCU pathway involving hydrogen faces the persistent challenge of electrolyser economics. While proton exchange membrane (PEM) electrolyser costs have declined 40% since 2020, they remain at USD 700-1,200 per kilowatt, well above the USD 200-400 target needed for unsubsidised e-fuel competitiveness. Alkaline electrolysers offer lower capital costs but inferior dynamic response characteristics for coupling with variable renewable generation. China's electrolyser manufacturing capacity (estimated at 13 GW per year in 2025) is driving cost reduction, but quality and durability concerns remain for deployment in high-value fuel synthesis applications.

Carbon Accounting Complexity

Lifecycle emissions accounting for CCU products remains contentious and inconsistently standardised. Products that temporarily store CO2 (fuels, short-lived chemicals) do not provide the same climate benefit as permanent mineralization, yet current carbon credit methodologies often fail to differentiate adequately. The ISO 14068 standard for carbon neutrality and the EU's delegated acts under the Renewable Energy Directive are establishing clearer boundaries, but inconsistent implementation across Asia-Pacific jurisdictions creates compliance uncertainty for multinational product teams.

Renewable Electricity Availability

CCU pathways that depend on green hydrogen require enormous quantities of dedicated renewable electricity. Producing 1 million tonnes of e-methanol consumes approximately 11 TWh of renewable electricity annually, equivalent to the output of 3-4 GW of offshore wind capacity. In Asia-Pacific, competition for renewable electricity between direct electrification, green hydrogen for industrial use, and CCU creates allocation tensions that policymakers have not yet resolved. Without dedicated renewable capacity, CCU projects risk increasing grid carbon intensity by consuming electricity that would otherwise displace fossil generation.

Key Players

Established Leaders

CarbonCure Technologies dominates the concrete mineralization segment with 700+ installations globally and active expansion across Asia-Pacific.

Carbon Recycling International operates the world's most established CO2-to-methanol facility and is licensing technology for large-scale Chinese deployment.

HIF Global (Porsche AG) leads e-fuel commercialisation with multi-site development in Chile, Australia, and the US.

Emerging Innovators

Blue Planet Systems manufactures synthetic aggregate from captured CO2, targeting Asian construction markets via licensing partnerships.

Twelve develops electrochemical CO2 conversion to chemicals and fuels, with Asia-Pacific demonstration projects underway.

Brimstone is reimagining cement production to eliminate process emissions entirely while generating net-negative supplementary cementitious materials.

Key Investors and Funders

Breakthrough Energy Ventures has invested across multiple CCU pathways including CarbonCure, Brimstone, and Twelve.

Japan's Green Innovation Fund provides the largest single-government allocation to carbon recycling R&D at JPY 2 trillion.

Temasek Holdings (Singapore) has invested in several CCU startups targeting the Southeast Asian construction and chemicals markets.

Action Checklist

• Map your product portfolio against CCU pathway readiness levels to identify where CO2-derived inputs could replace conventional feedstocks within 3-5 years
• Evaluate carbon mineralization products (CO2-cured concrete, synthetic aggregate) for near-term procurement, as these offer the strongest economics and permanence profile
• Assess regulatory exposure to EU CBAM and emerging Asia-Pacific carbon pricing for products with embedded fossil carbon
• Model e-fuel adoption timelines against applicable blending mandates (aviation, maritime) in target markets
• Engage with CCfD programmes where available to de-risk early adoption of CO2-derived chemical feedstocks
• Establish lifecycle carbon accounting capabilities aligned with ISO 14068 and relevant regional standards
• Monitor electrolyser cost trajectories as the primary leading indicator for hydrogen-dependent CCU pathway viability
• Evaluate vertical integration opportunities in renewable electricity to capture margin in e-fuel value chains

FAQ

Q: Which CO2 utilization pathway offers the best near-term economics without subsidy dependence? A: Carbon mineralization into building materials, particularly CO2 injection into concrete (CarbonCure model) and synthetic aggregate production (Blue Planet model), currently offers the strongest unsubsidised economics. These pathways benefit from low energy requirements, permanent carbon storage, and alignment with the massive global construction materials market. E-fuels and most chemical synthesis pathways remain subsidy-dependent at current renewable electricity and electrolyser costs.

Q: How should product teams evaluate the permanence claims of different CCU products? A: Apply a simple framework: mineralized products (concrete, aggregate, synthetic limestone) store CO2 for geological timescales (10,000+ years). Polymers and durable chemicals store CO2 for the product lifetime (typically 10-50 years). Fuels re-emit CO2 upon combustion, providing zero net removal benefit but potentially displacing fossil fuel emissions. Permanence matters for carbon credit eligibility and should inform procurement decisions where climate impact claims are part of product positioning.

Q: What is the realistic timeline for e-fuel cost competitiveness with conventional fuels? A: At current trajectories, e-kerosene costs are projected to decline from USD 3,000-5,000 per tonne today to USD 1,200-2,000 per tonne by 2030, driven primarily by electrolyser cost reductions and renewable electricity cost declines. Conventional jet fuel prices of USD 600-900 per tonne mean e-fuels will likely require blending mandates or carbon pricing above USD 200 per tonne to achieve market parity before 2035. In Asia-Pacific specifically, Japan and South Korea's willingness to mandate blending creates captive demand regardless of cost parity timing.

Q: How does China's dominance in electrolyser manufacturing affect CCU economics in Asia-Pacific? A: Chinese electrolyser manufacturers (LONGi Hydrogen, Peric, Sungrow) are producing alkaline systems at USD 200-400 per kilowatt, approximately 50-60% below Western equivalents. This cost advantage accelerates the economics of hydrogen-dependent CCU pathways across Asia-Pacific, but raises supply chain concentration risks and quality concerns for applications requiring high uptime and precise hydrogen purity. Product teams sourcing CCU technologies should evaluate electrolyser provenance as a factor in project risk assessment.

Q: Are CO2-derived chemicals genuinely competitive with petrochemical alternatives? A: At a carbon price of EUR 80-100 per tonne (current EU ETS levels), CO2-derived methanol approaches cost parity with fossil methanol in Europe. In Asia-Pacific, where carbon pricing ranges from zero to USD 20 per tonne in most jurisdictions, CO2-derived chemicals remain 30-80% more expensive than conventional alternatives. The exception is where green premiums exist in end markets: consumers of CO2-derived polyols for mattresses and automotive components have demonstrated willingness to pay 15-25% premiums for verified low-carbon materials.

Sources

• McKinsey & Company. (2025). The CO2 Utilization Market: Sizing the Opportunity Across Pathways. McKinsey Sustainability Practice.
• International Energy Agency. (2025). CO2 Utilization in the Asia-Pacific: Technology Readiness and Policy Landscape. Paris: IEA Publications.
• Japan Ministry of Economy, Trade and Industry. (2025). Green Innovation Fund: Carbon Recycling Progress Report FY2024. Tokyo: METI.
• Global CCS Institute. (2025). Global Status of CCS and CCU: 2025 Report. Melbourne: GCCSI.
• BloombergNEF. (2025). Hydrogen Economy Outlook: Electrolyser Costs and Deployment Projections. New York: Bloomberg LP.
• CarbonCure Technologies. (2025). Annual Impact Report: CO2 Mineralization in Concrete Production. Halifax: CarbonCure.
• Mission Innovation. (2025). Carbon Dioxide Removal and Utilization: Innovation Challenges Progress Report. Brussels: MI Secretariat.