Enormous value rejected through boiler and generator exhaust, condenser heat, cooling towers, blowdown and stack losses. Coal adds particulate.
Power plants reject enormous value through boiler and generator exhaust, condenser heat, cooling towers, blowdown, stack losses and auxiliary systems. Where site conditions, fuel chemistry, emissions controls and independent measurement support it, this is a near-zero emissions opportunity — treated as an engineered project objective, not a regulatory guarantee, until it is demonstrated.
| Case | Present setup & waste | SRU / RPC / TESS response | Target outcome |
|---|---|---|---|
| 500 MW gas plant | Example output 12,000 MWh/day; fuel input may exceed 22,000–25,000 MWh(th)/day depending on heat rate. Waste: stack heat, condenser and cooling load, turbine exhaust, auxiliary losses. | SRU captures exhaust heat and water-vapour value where chemistry permits. TESS stores and reuses heat, and converts sufficient-temperature heat to behind-the-meter power. No RPC unless a particulate or fuel condition requires it. | Target 7–10% fuel reduction and ~25% useful output increase where integration supports it, plus black-start TESS backup for key plant infrastructure. |
| 500 MW coal plant | Example output 12,000 MWh/day; fuel input may exceed 30,000 MWh(th)/day. Waste: particulate exhaust, stack heat, condenser heat, ash and solids, cooling-tower burden, auxiliary loads. | RPC addresses the particulate-heavy exhaust. SRU captures heat and water-vapour value where chemistry permits. TESS stores and converts recoverable thermal streams. Greenhouse or compression/condensation pathways create public-facing value. | Near-zero emissions opportunity when combined with proper emissions controls; 7–10% fuel reduction target, ~25% net MWh increase target, and 40–60% cooling-water reduction target where engineered and validated. |
W.A. Parish, near Thompsons in Fort Bend County, is one of Texas's largest mixed-fuel stations: 3,632 MW reported, made up of 2,514 MW coal and 1,118 MW natural gas. We used it as a planning example of what the retrofit could add. On coal units, exhaust passes through the RPC before the SRU. TESS connects to the recovered-heat circuits, and the recovered heat, water and CO₂ can feed an agriculture link beside the plant.
| Measure | As-is index | Proposed target |
|---|---|---|
| Fuel input | 100 | 90–93 |
| Net electricity | 100 | 120–125 |
| Fuel per MWh | 100 | 72–77.5 |
| Affected cooling water | 100 | 40–60 |
| Pollution | Measured baseline | Fewer particles; gas-specific controls retained |
| Annual measure | Baseline | Target range |
|---|---|---|
| Net electricity | 700,800 MWh | 840,960–876,000 MWh |
| Gas consumption | 6.307M MMBtu | 5.676–5.866M MMBtu |
| Power receipts at $50/MWh | $35.04M | $42.05–43.80M |
| Fuel cost at $4/MMBtu | $25.23M | $22.71–23.47M |
Extra electricity receipts plus fuel savings for a 100 MW plant at 80% utilization and a 9.0 MMBtu/MWh heat rate. The figure is before added O&M, debt, tax and carbon capture, and it is not EBITDA. Sensitivity: $5.5–17.8M/year across $30–80/MWh power and $3–6/MMBtu gas. The downside case (+5% MWh, −3% fuel) is $2.5M/year. The same heat is never counted twice across fuel savings, ORC generation and greenhouse heating.
This assessment assumes no actual Parish fuel, generation, water or emissions baseline. RPC particle removal alone does not remove sulfur gases or CO₂, so required pollutant controls stay in place. Near-zero emissions would also require a separate carbon capture-and-storage pathway. The next step is a measured demonstration that meters fuel, net MWh, water and pollutant mass emissions.
RPC removes the solid pollutants. SRU and TESS strip the Btus across an 800°F-to-122°F cascade and convert what qualifies into behind-the-meter electricity. What remains — CO₂ and water vapour — becomes the input to a greenhouse complex producing food year-round.
The Sidel RPC removes fine particulate — unburned fixed carbon and fly ash — from coal-plant flue gas before it reaches the stack. Today that material is typically landfilled at the plant's expense. Once separated and characterised, it's a consistent, sized, reusable industrial feedstock: a stable mix of unburned fixed carbon and fine mineral residue (silica, alumina and metal oxides).
Material otherwise landfilled at the plant's expense is diverted to a paying market across cement, refractories, abrasives, insulation, construction and emergency response — one captured feedstock, many buyers. Modeled on published industry data for a representative 500 MW coal-fired plant: ~1.4M tons of coal burned per year generates ~125,000 tons of ash, of which ~100,000 tons is fine particulate available for RPC capture. At current fly-ash market prices of roughly $40–$122/ton, that models to $4M–$12M+/year in potential revenue — a benchmark to refine against plant-specific ash characterization and buyer specifications, not a quote.
We would rather send you a data request than a brochure. This is what turns a conversation into a bankable project.
Plant heat rate; turbine and exhaust temperature and flow; cooling technology and water balance; auxiliary load; dispatch profile; power price; emissions permit; black-start requirements; interconnection limits; available footprint.
Coal quality; ash and particulate loading; flue-gas chemistry; existing ESP / baghouse / FGD / SCR controls; boiler data; condenser and cooling-tower water balance; auxiliary load; ash handling; corrosion and condensate constraints; emissions permits.
All claims relating to site savings, water reduction, output increase, emissions outcomes, payback, incentives and deployment economics are planning assumptions, analogues or prior-project references — unless and until they are validated for your specific facility through engineering, measurement, vendor quotation, financing documentation, legal review and final commercial agreements.