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Turn gas-fired power plant emissions into $85/ton 45Q tax credits and $400-850/ton CaCO₃ product revenue with 5-12 month modular deployment.
Gas-fired combined cycle turbines and peaking generators produce 3–5% CO₂ flue gas — a dilute stream that conventional capture struggles with. The Carbon to Crystals process was engineered specifically for these concentrations, achieving a verified 99% capture rate and converting waste gas into a dual-revenue asset.
Natural gas power plants emit approximately 0.4 tons CO₂ per MWh of electricity generated. A 100 MW facility operating at 85% utilization generates roughly 140,000 tons of CO₂ annually, while a 500 MW combined cycle plant produces over 700,000 tons per year.
F-class gas turbine flue gas contains 3–5% CO₂ at 300–500°C — a high-temperature but dilute stream that is ideal for mineralization capture. After the steam turbine and heat recovery steam generator (HRSG), concentrations remain stable at 3–4%, making them predictable targets for modular skid placement.
Peaking generators and data center backup turbines operate at lower utilization but present the same 3–5% CO₂ challenge. Because they run on demand, traditional CCS requiring 18–36 months of construction is economically infeasible. Modular Carbon to Crystals units attach directly to existing gas stacks and scale to the turbine's output profile, capturing emissions whether the unit runs 500 hours or 8,000 hours per year.
Traditional amine scrubbing costs $61–$80/ton in capture OPEX alone, plus pipeline transport and geological injection costs. For power plants without nearby CO₂ infrastructure, the total cost per ton captured easily exceeds the $85/ton credit — making 45Q economics negative or barely breakeven.
Carbon to Crystals mineralization eliminates transport and injection entirely, converting CO₂ into a 98% pure, sellable CaCO₃ solid on-site. The dual-revenue baseline — $85/ton in federal credits plus $400–$850/ton in mineral product sales — generates net positive returns at any plant size and any utilization rate.
The OBBBA 2025 enhanced 45Q rates of $85/ton require physical construction to begin before January 1, 2033. For power generation facilities planning carbon capture, this creates a hard deadline: 18–36 month traditional CCS projects started after late 2030 will miss the window entirely.
Modular Carbon to Crystals deploys in 5–12 months. A facility that identifies the need in 2032 can still have skids installed, operational, and capturing CO₂ before year-end. At $85/ton and 140,000 annual tons for a 100 MW plant, missing the deadline means forfeiting $11.9M per year in federal credits for 12 years — $142.8M in total lost value.
Yes. Gas-fired combined cycle plants produce flue gas with 3–5% CO₂, which is ideal for Carbon to Crystals mineralization. Traditional amine scrubbing at these concentrations costs $61–$80/ton and degrades rapidly. Our proprietary aqueous chemistry achieves a verified 99% capture rate at dilute concentrations.
A 100 MW natural gas facility generates approximately 0.4 tons CO₂ per MWh, or roughly 140,000 tons CO₂ annually at 85% utilization. At $85/ton, that is $11.9M per year in federal credits, totaling $142.8M over 12 years — before any CaCO₃ product revenue.
Mineralization permanently converts CO₂ into solid CaCO₃, eliminating the need for pipeline transport and underground injection wells. Post-OBBBA 2025, mineralization qualifies for the same $85/ton 45Q credit rate as geological storage, while generating additional product revenue that storage cannot match.
Tonnage Edition: Calculate the value of your mineral waste stream.
+ $180 profit per ton of residue
*Estimates based on 10% replacement rate. Actual results may vary.
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