Tire Pyrolysis Oil Is the Loss Leader. The Carbon Black Pays for the Plant.

Here's the opinion most tire pyrolysis developers won't hear from their EPC contractor: tire pyrolysis oil is a loss leader. The plant only pencils if you sell the recovered carbon black — and most projects I'm seeing in 2026 are still building the pro forma around the oil. That's the wrong product to optimize for, and cement kilns are the wrong primary customer.

I've spent twenty years in waste-to-energy plant operations and helped commission three facilities — one in the US Midwest, two abroad — that processed feedstocks ranging from MSW to whole tires. The tire one nearly broke me, financially and otherwise. Not because the technology didn't work. Because we'd structured the offtake around cement kilns paying what tire pyrolysis oil "should" be worth on energy content alone, and they don't. They pay what they pay for tire-derived fuel, minus a discount for handling a liquid. That's the whole story, and it cost us about eighteen months of margin to learn it.

What cement plants actually pay

The number I keep hearing at conferences is "diesel parity." Tire pyrolysis oil clocks in at 42–43.5 MJ/kg, comparable to diesel's 45 MJ/kg [per a 2023 Polymers review of waste tire pyrolysis, https://www.mdpi.com/2073-4360/15/7/1604], so surely it should price near a diesel-equivalent BTU? It doesn't. Cement kilns benchmark against coal, petcoke, and whole-tire TDF — not diesel.

Whole-tire TDF in North America trades roughly $50–$80 per ton at the kiln gate [per Cognitive Market Research's 2025 TDF market analysis, cognitivemarketresearch.com], with the US average closer to $25–30/ton in many regions [industry estimate, 2024–2025] and as low as $15 in oversupplied geographies [operator data, southeastern US]. That's the alternative your buyer is comparing you to. They aren't comparing your liquid pyrolytic oil to diesel because they don't burn diesel. They're comparing it to crushed tire chips delivered on a tipper.

The math isn't kind. Even if you can argue a 25–35% premium over chip-form TDF on the basis of feed flexibility, dosing precision, and reduced ash loading, you're looking at maybe $80–$110 per ton at the kiln gate in 2026 dollars [market range, Q1 2026, based on operator quotes in our project files]. Strip out trucking, storage demurrage, and the inevitable sulfur surcharge — TPO runs 1.0–2.0 wt% sulfur versus diesel's <0.05 wt% [per the 2023 Polymers review] — and net to the producer often lands closer to $60–$85 per ton.

At a 50% oil yield from feedstock [a 2022 J. Air & Waste Mgmt. review reports oil yields of 44–58 wt% depending on temperature, tandfonline.com], that's $30–$42 of oil revenue per ton of tire processed [engineering estimate using midpoint pricing]. You'll spend more than that on natural gas keeping the reactor at 500–550°C [reactor operating range, per the 2023 Polymers review] and on electricity for the condenser train [RWE commissioning data, 2019 facility].

And cement kiln procurement teams know all this. They're a sophisticated buyer. The biggest North American cement groups have been blending TDF since the 1990s. They know your alternatives, they know your storage costs, and they have petcoke contracts to fall back on if you push price. The 2023 USTMA end-of-life tire report noted TDF cement kiln consumption rose 15% year-over-year [per USTMA's 2023 ELT report], which sounds bullish until you realize the price didn't move with it. Supply expanded into the demand.

The carbon black is the actual product

Here's where the conversation needs to pivot. Every ton of waste tire pyrolysis through a properly tuned reactor yields, roughly: 50% oil, 35% char (recovered carbon black, or rCB), 12% gas, and 3% steel [from the 2023 Polymers literature review]. That char fraction is the difference between a project that pencils and one that doesn't.

Pyrolytic carbon black, post-treatment, sells into rubber compounding, plastics masterbatch, and pigment markets at $400 to $1,200 per ton depending on grade and consistency [market range, Q1 2026, RWE project experience]. A specification-grade rCB that competes against virgin N550 or N660 carbon black can clear $900+ per ton in long-term offtakes. That's an order of magnitude above what the oil clears at a cement gate.

Run the same ton-of-tire math: 0.35 ton of rCB at $600/ton (mid-grade) = $210 [engineering estimate using mid-band rCB pricing]. Oil contributes maybe $35 net [based on the cement-gate math above]. The pyrolytic gas usually goes back to firing the reactor and isn't a cash product. The steel comes out at $80–$150/ton scrap [LME-tracked scrap range, Q1 2026], so call it $30 from the steel fraction. Of your roughly $275 gross product revenue per ton of tire, three-quarters comes from the carbon black.

And cement plants are not the buyer for that.

The counterargument I hear most

"But we're upgrading the oil. Hydrotreating gets it to diesel-grade. We won't be selling at TDF prices, we'll be selling at diesel-plus."

Sure. And the hydrotreater costs $30 to $60 million for a meaningful throughput [vendor quote range, RWE feasibility files 2022–2024], requires hydrogen you don't make on-site, and adds 10–15% to operating cost per ton of finished oil [engineering estimate, RWE project models]. I sat through a feasibility study in 2022 where the model assumed hydrogen at $1.50/kg. Local price was $4.20 [merchant H2 quote, US Gulf, mid-2022]. The project died at the integration committee meeting. Hydrotreating works for refineries that already have hydrogen plants, hydroprocessing units, and a sales team with relationships at fuel terminals. It does not work for a 60 TPD tire plant in a secondary market.

Catalytic upgrading at the reactor — using red mud, zeolites, or molybdenum-based catalysts — can drop sulfur by 60–88% in lab studies [per a 2024 PMC paper on red mud catalysts, pmc.ncbi.nlm.nih.gov]. Lab. I've yet to see one of these systems hold spec for more than a few weeks at commercial scale. The catalyst gets fouled by zinc and ash carryover, regeneration cycles eat throughput, and the sulfur creeps back up. Maybe by 2030 the kinks are out. Today, I wouldn't underwrite a project on it.

Where my contrarian view doesn't hold

I should name where I'm wrong, because I'm not always right.

If you're operating somewhere with a regulated EPR (extended producer responsibility) scheme that pays per-ton processing fees — parts of the EU, Quebec, Korea — the gate fee is your actual primary revenue. You're getting paid $80–$200 per ton just to take the tires. In that world, the oil-versus-rCB argument matters less because you've already covered fixed costs at the gate. I've watched a Korean operator run profitably on oil-only offtake because their EPR fee was $190/ton. That's a structurally different business than a US Gulf-region plant chasing voluntary feedstock at $0/ton tip.

Second caveat: very small plants — under about 30 TPD [based on RWE feasibility reviews of sub-scale operators] — often can't justify the rCB upgrading equipment. Pelletizing, milling, surface treatment runs $1.5–$3M of capex [vendor quotes for ~5,000 TPY rCB lines, 2024], and at small volumes you can't amortize it. Those operators end up selling raw char at $80–$150/ton [market range for unbeneficiated pyrolytic char, Q1 2026] into low-grade applications. At that price, oil and char are roughly equivalent revenue contributors and my contrarian argument weakens. The economics I'm describing really start working above ~80 TPD with a buyer relationship for treated rCB.

Third: if you've got a captive cement plant under common ownership willing to take the oil at a favorable transfer price, the calculus changes. That's a corporate finance question more than a market question, and your CFO will run it differently than I would.

What went wrong on our 2019 project

The 80 TPD facility I helped commission in 2019 [RWE project records, anonymized] sold its oil for the first eighteen months at an average of $0.18/liter (~$200/ton at typical density of ~0.9 g/cm³ per the 2023 Polymers review). We thought we'd cracked it. The buyer was a regional asphalt producer mixing the oil into emulsifier formulations. Then their formulation changed, the buyer disappeared in eight weeks, and we spent three months scrambling for a cement kiln offtake at $90/ton [actual contracted gate price, late 2020, RWE records]. We also lost three days to a sensor calibration issue the vendor insisted was impossible. We lost six months of margin to assuming our boutique buyer would stay around.

The carbon black side, by contrast, was undersold. We had a tire compounder taking everything we could produce at $480/ton [RWE project records, 2020 contract], and we were so focused on the oil offtake renegotiation that we didn't push our rCB volume up until late 2021. When we finally invested in a pelletizer and surface-treatment line — about $2.1M of capex [RWE capex records] on a plant originally scoped to spend $4M on oil polishing [original FEED estimate, 2018] — payback was under fourteen months [from operator P&L]. That decision should have been made on day one of the design phase. I'd estimate I cost the project something like $4M in foregone gross margin by waiting two years [back-of-envelope from delta in rCB pricing pre/post upgrade].

That's the lesson I keep repeating to anyone who'll listen: the rCB line is not optional. It's the project. The oil is the byproduct that finds a home.

Implications for your project plan

If you're scoping a waste tire pyrolysis facility in 2026, three things should change in how you build the case.

First, design the rCB pelletizing and post-treatment line into the base capex. Don't make it a phase-two upgrade. The thermal pyrolysis system is the easy part — most reactor vendors can deliver a working unit, and the differences between them matter less than the brochures suggest. The post-processing on the carbon side is what determines whether you sell at $200/ton or $700/ton, and retrofit costs run 1.4–1.8x the cost of designing it in from the start.

Second, have your rCB offtake letter of intent in hand before you order long-lead reactor equipment. Sample requirements from rubber compounders are stringent — they'll typically ask for 100 kg samples [typical compounder qualification volume, RWE offtake negotiations 2020–2024] meeting ASTM D1765 grade tolerances before they sign anything. That qualification process alone runs six months [average across three RWE projects]. If your business case relies on $600/ton rCB pricing [mid-band per the Q1 2026 market range cited above], you need a buyer who'll pay $600/ton for a specific spec, not a market-research average.

Third, model the oil at $60–$90/ton net of logistics [conservative band based on the cement-gate analysis above], with a sensitivity case at $30/ton [stress case anchored to oversupplied US TDF spot pricing] for periods when your nearest cement kiln has petcoke at distressed prices. The oil revenue should keep the lights on between rCB shipments. It shouldn't be the basis for your IRR. Plants that flip those two — oil as primary, char as bonus — are the ones I see fail or refinance under duress within five years [pattern across roughly a dozen project audits, RWE advisory practice].

And site selection follows from this. A tire pyrolysis plant should be sited near rubber and plastics compounders who'll buy your rCB, not near cement plants. The oil is liquid, easy to truck a hundred miles. Carbon black is bulkier per dollar of revenue and benefits from short-haul logistics into a relationship buyer. We had this exactly backwards in 2019 — sited near a cement plant, hours from any compounder.

For developers thinking about this in the broader context of waste-to-energy technology choices, the same logic shows up elsewhere: the highest-value product fraction usually isn't the one that gives the project its name. Plastic pyrolysis oil follows similar dynamics with the wax and carbon fractions, and biomass pyrolysis systems often only work because of the biochar credit, not the syngas. The naming convention is a hangover from a refining industry that thought of liquids as the prize.

So here's the position again, sharper than I opened it. Tire pyrolysis oil is not the product. It's the heat sink and the byproduct stream. The plant built around it will struggle and most of the ones I've audited since 2020 are struggling. The plant built around recovered carbon black, with the oil sold to whoever will take it nearby on a short-haul contract, has a real shot. Cement kilns are an offtake of last resort, not a primary customer. Stop pricing them as if they were.

If you're sizing a project in this space and want a second pair of eyes on the offtake structure before signing reactor procurement, RWE's zero-waste-to-landfill solutions advisory practice reviews these models regularly. We've seen the version where it works and the much more common version where it doesn't.

Disclosure: I work with Renewable Waste Energy as a senior plant engineer. The numbers in this article come from project experience and the published sources listed below; specific commercial terms are anonymized to protect prior client relationships.

Sources & Notes

1. Pyrolysis of Waste Tires: A Review (Polymers, MDPI, 2023) — heating value, sulfur content, oil/char/gas yield distribution. mdpi.com/2073-4360/15/7/1604
2. Waste tire pyrolysis and desulfurization of tire pyrolytic oil — A review (Journal of the Air & Waste Management Association, 2022) — oil yields by reactor temperature, desulfurization techniques. tandfonline.com
3. Production of low-sulfur fuels from catalytic pyrolysis of waste tires using formulated red mud catalyst (PMC, 2024) — catalytic desulfurization performance figures. pmc.ncbi.nlm.nih.gov/articles/PMC11261096
4. Tire Derived Fuel Market Report 2025 (Cognitive Market Research) — TDF gate prices, cement segment share, market sizing. cognitivemarketresearch.com
5. USTMA 2023 End-of-Life Tire Management Report — US TDF consumption growth, cement kiln share. ustires.org/2023-elt-tire-report-page
6. RWE project records — anonymized commissioning and operating data from an 80 TPD tire pyrolysis facility (2019–2022) and reviewed feasibility studies (2022, 2024).