Carbon Startup Spiritus Turns Captured CO2 Into Oilfield Sales
Spiritus has struck preliminary deals with three U.S. oil and gas producers to sell captured CO2 for enhanced oil recovery, a business-model shift driven by thinner federal carbon capture incentives.
Carbon management engineering company Spiritus has signed preliminary agreements with three U.S. oil and gas producers to sell them captured carbon dioxide for enhanced oil recovery, as cuts to federal carbon capture incentives push start-ups toward revenue from oil companies rather than storage subsidies.
A carbon removal company that was built to bury carbon dioxide underground is now lining up buyers who want to pump it back into oil reservoirs. Spiritus, a carbon management engineering firm, has signed preliminary agreements with three U.S. oil and gas producers to sell them captured CO2 for enhanced oil recovery, according to OilPrice.
The move is small in isolation. As a signal about how climate-technology companies intend to survive a thinner subsidy environment, it is not small at all.
Why a carbon removal firm is selling to drillers
The original pitch for direct air capture and similar technologies was straightforward: pull CO2 out of the atmosphere, put it in a deep geological formation, and get paid — partly by federal tax credits, partly by corporations buying carbon removal credits. That model depends on public policy staying generous and predictable.
Neither condition currently holds. Cuts to U.S. federal incentives for carbon capture projects, combined with an uncertain regulatory outlook, have pushed some start-ups to look for a customer who will write a cheque today rather than a credit that may or may not arrive later. Oil producers are that customer. They have used CO2 in the field for decades, they understand the logistics, and they value the gas for what it does to a reservoir rather than for what it does to the atmosphere.
Injecting CO2 into a mature oil field reduces the viscosity of the crude left behind after conventional production has run its course, allowing more of it to flow to the wellbore. That is enhanced oil recovery, or EOR — and the lead facts are explicit that the CO2 in these agreements is destined for exactly that use, unlocking additional oil from reservoirs the producers already own.
The awkward arithmetic of selling carbon to oil companies
For the climate constituency that funded companies like this, the trade is uncomfortable. CO2 delivered for EOR does end up underground — a substantial share of injected gas stays in the formation — but it is being used to produce hydrocarbons that will themselves be burned. Whether the net carbon accounting works depends on how much CO2 stays put, how much oil is recovered, and which accounting standard you apply. None of those variables are settled, and none are specified in these preliminary agreements.
What is clear is the commercial logic. An EOR contract gives a capture company something it cannot get from a subsidy: a counterparty with existing infrastructure, an operational need, and a reason to pay for volume rather than for a verified environmental outcome. That makes revenue easier to forecast and easier to finance. Lenders and equity investors have been notably cold on pre-revenue climate hardware; a signed offtake with a producer changes the conversation.
It also concentrates risk. A capture company whose demand comes from oil producers is now exposed to the oil price. When crude is weak, marginal EOR projects are the first to be shelved, and the CO2 buyer's appetite evaporates with them. The business has traded policy risk for commodity risk — arguably a fairer trade than it sounds, given how policy has behaved, but a trade nonetheless.
What the agreements do and do not tell us
These are preliminary agreements, not binding long-term supply contracts. The lead does not name the three producers, disclose volumes, pricing or delivery dates, and it would be wrong to assume any of them convert. Preliminary deals in the CO2 business frequently stall on the unglamorous parts: pipeline access, compression, permitting for injection wells, and who bears the cost of measurement and verification.
Three things are worth watching as this develops:
- Conversion. Whether the preliminary agreements become firm offtake contracts with stated volumes. That is the test of whether producers see CO2 supply as strategic or opportunistic.
- Who else follows. If other capture start-ups announce EOR offtakes, the shift stops being one company's pivot and becomes the sector's default commercial model.
- The policy response. Federal incentive design determines whether storage-only projects can compete with EOR buyers for the same molecules. Further tightening pushes more supply toward the oilfield.
The broader energy backdrop
The lead does not name the three producers, disclose volumes, pricing or delivery dates, and it would be wrong to assume any of them convert.
This is happening while the market is in a cautious mood. As of the last trade at 16:13 GMT on Wednesday, the S&P 500 tracking fund (NYSEARCA: SPY) was at $768.65, down 0.61% on the day from a previous close of $773.38, with a session range of $768.23 to $773.59. The Nasdaq 100 proxy (NASDAQ: QQQ) was at $740.67, off 0.91%, and the Dow 30 fund (NYSEARCA: DIA) at $514.86, down 0.61%. Broad risk appetite was modestly negative across all three benchmarks — not a crisis tone, but not the environment in which speculative energy-transition capital flows freely either.
That context matters for how to read the Spiritus deals. Capital discipline is the operating condition for climate hardware right now. Companies that can point to a paying industrial customer are in a different financing category from those pointing to a tax credit and a corporate pledge.
What this means for producers
For the oil and gas side, cheap or contracted CO2 supply is a useful input rather than a strategic revolution. EOR economics depend on the delivered cost of CO2 per unit of incremental barrel recovered, and on the oil price at the far end. A producer that secures supply from a capture company rather than a natural CO2 dome or a gas processing plant gains optionality and, potentially, a story to tell about the carbon intensity of the resulting barrels.
That story has value with lenders, insurers and some buyers, even if environmental groups dispute the framing. The interesting question is whether producers eventually pay a premium for atmospherically sourced CO2 — which would make direct air capture genuinely commercial — or simply treat it as one more supplier bidding into a price-driven procurement process. At the moment, nothing in these preliminary agreements settles that.
The broader point stands: when public incentives shrink, climate technology does not necessarily die. It finds the customer that was always willing to pay — and in the carbon business, that customer drills for oil.
Frequently asked questions
What did Spiritus actually sign?
Spiritus, a carbon management engineering company, signed preliminary agreements with three U.S. oil and gas producers to sell them captured carbon dioxide. The CO2 is intended for enhanced oil recovery. The agreements are preliminary rather than binding long-term supply contracts, and the producers, volumes, pricing and delivery timelines have not been disclosed.
What is enhanced oil recovery?
Enhanced oil recovery, or EOR, is a set of techniques used to extract crude that conventional drilling leaves behind. Injecting carbon dioxide into a mature reservoir reduces the oil's viscosity and helps it flow toward the wellbore. U.S. producers have used CO2 flooding for decades, so the infrastructure and operational know-how already exist.
Why are carbon capture start-ups changing their business model?
Cuts to U.S. federal incentives for carbon capture projects, together with an uncertain regulatory outlook, have made subsidy-dependent storage economics harder to finance. Selling CO2 to oil producers gives these companies a paying industrial customer and a more predictable revenue line, rather than relying on tax credits or voluntary corporate carbon removal purchases.
Does CO2 used for oil recovery still count as stored?
Partly. A substantial share of injected CO2 remains trapped in the formation, but the process also produces additional oil that will be burned. Whether the net carbon balance is positive depends on retention rates, recovery volumes and the accounting standard applied. Those variables are disputed and are not specified in the preliminary agreements.
What risks does this shift create for capture companies?
It substitutes policy risk for commodity risk. A capture firm whose demand comes from oil producers is exposed to the crude price, because marginal EOR projects are among the first shelved when oil weakens. Preliminary deals can also stall on pipeline access, compression costs, injection-well permitting and responsibility for measurement and verification.
What were markets doing when the news landed?
As of the last trade at 16:13 GMT on 23 September 2026, the S&P 500 tracking fund SPY was at $768.65, down 0.61% from a prior close of $773.38. The Nasdaq 100 proxy QQQ was at $740.67, down 0.91%, and the Dow 30 fund DIA stood at $514.86, down 0.61% on the day.
