The Texas Railroad Commission has approved a $5 billion carbon capture and storage project for ExxonMobil, clearing the way for injection of roughly 53 million metric tons of CO2 into three underground wells in the Beaumont-Port Arthur industrial corridor.

The commission voted 2-1 to grant the sequestration permit, with Commissioner Christi Craddick's office confirming Commissioner Ryan Sitton's counterpart Wayne Christian casting the dissent. The vote hands Spring, Texas-based ExxonMobil the state-level Class VI authorization it needs to scale its Gulf Coast CO2 storage business, which the company ranks as the world's first and largest CCS system.

The Financial Times broke the news. Dominic Genetti, senior vice president of CCS at ExxonMobil, told the paper the commission's action is a "major milestone" that allows the company to keep expanding along the Gulf Coast.

"The Railroad Commission clearly recognizes the important role carbon capture and storage can play in meeting growing global demand for lower-carbon products while supporting new jobs and economic growth," Genetti said.

What does the permit actually authorize?

The project covers three injection wells ExxonMobil has already drilled in the Beaumont-Port Arthur area. Over a 13-year injection window, the company plans to store about 4 million metric tons of CO2 per year in the Fleming and Upper Frio rock formations, according to Carbon Herald's reporting on the permit terms.

The CO2 will come from industrial customers — emitters with no on-site decarbonization path that are contracting third-party capture, transport and storage. That customer-facing model, rather than abating ExxonMobil's own stack emissions alone, is the commercial engine behind the $5 billion capital commitment.

The U.S. Environmental Protection Agency approved ExxonMobil's Rose CCS project last year, giving the company a federal anchor for the same corridor. The Railroad Commission permit adds the state-level storage authorization on top.

How does this fit ExxonMobil's pipeline network?

ExxonMobil says its CCS system already includes 1,300 miles of CO2 pipeline and dedicated storage sites — 70% of that pipeline mileage runs along the Gulf Coast, positioning the company to move captured CO2 from Louisiana and Texas industrial clusters to permitted pore space.

The network's growth traces to November 2023, when ExxonMobil closed its $4.9 billion acquisition of Denbury, an operator that owned roughly 1,000 miles of CO2 pipeline at the time of the deal.

"Our expertise, combined with Denbury's talent and CO2 pipeline network, expands our low-carbon leadership and best positions us to meet the decarbonization needs of industrial customers while also reducing emissions in our own operations," Chairman and CEO Darren Woods said when the transaction closed.

Genetti, in a January post on ExxonMobil's website, framed the commitment as durable rather than opportunistic: the company is in CCS "for the long haul."

"CCS is not new technology, but it's flown relatively under the radar compared with the attention that production of hydrocarbons commands," Genetti wrote. "Now, as the world becomes more aware of the need to reduce emissions, CCS finally has a brighter spotlight and a broader runway to scale up."

Is injection already running elsewhere?

Yes. The same week as the Texas permit, ExxonMobil announced it has begun CCS operations at a direct reduced iron facility in Convent, Louisiana. That project will capture, transport and store up to 800,000 metric tons of CO2 per year — the company's first operating tie-in with lower-carbon steel production on the Gulf Coast.

The Convent start-up matters for the Beaumont-Port Arthur rollout: it demonstrates the integrated capture-transport-storage chain at commercial scale before the larger Texas volumes come online. The 800,000-tonne Louisiana stream is a fraction of the 4 million tonnes per year the Texas wells are designed to absorb.

What decides what happens next?

Watch the injection ramp. The permit's 13-year timeline and 4-million-tonne annual target now sit against ExxonMobil's execution record — converting state authorization into contracted, measured, permanently stored tonnes. EPA oversight of the Rose CCS project, additional Class VI permitting for future well sites, and industrial customers' willingness to sign long-term offtake for capture and storage will determine whether the $5 billion program hits its throughput or stalls as announced capacity. The next hard checkpoint is first injection at the Beaumont-Port Arthur wells.