The $30 Billion Question: Who Pays for Carbon Capture Leak Liability?

The United States is pouring unprecedented capital into carbon capture and storage (CCS), driven by the federal 45Q tax credit that pays up to $85 per metric ton of sequestered CO2. But as the first wave of commercial-scale projects moves from the drawing board to active injection, a massive financial vulnerability is emerging. Carbon dioxide pumped into deep geologic formations must remain trapped indefinitely to benefit the climate. If a reservoir fractures or an old wellhead fails decades from now, the resulting leak poses both a localized asphyxiation hazard and a clawback of federal tax credits.[3]

This reality has exposed a multi-billion-dollar question that is fracturing the emerging CCS industry: who holds the liability for the carbon after the facility closes? The federal baseline, governed by the Environmental Protection Agency’s Class VI well regulations, technically vests liability with the well owner in perpetuity. However, the EPA allows states to assume primary regulatory authority over these wells, and state legislatures are now diverging sharply on how to handle the long-term risk.[3]

The stakes are highest in California, which recently saw its first commercial carbon-storage project begin operations. California Resources Corp. (CRC) is injecting CO2 into depleted reservoirs at the Elk Hills oil field in Kern County. The project, known as Carbon TerraVault I, is permitted to store up to 1.46 million tonnes of CO2 annually, with a total lifetime capacity of 38 million tonnes.[1][5]

Carbon storage does not generate revenue on its own; it relies entirely on public subsidies and carbon markets. At Elk Hills, CRC can stack federal 45Q tax credits, California’s Low Carbon Fuel Standard credits, and cap-and-trade benefits. If the company’s statewide storage plans scale up to their full potential, CRC and its affiliates could capture as much as $30 billion in public incentives over the life of the projects.[1]

With billions of taxpayer dollars on the table, environmental advocates and state lawmakers argue that the public should not also underwrite the risk of failure. In 2022, California passed Senate Bill 905, which mandates that CCS operators maintain financial responsibility for at least 100 years after the last date of injection. The California Air Resources Board (CARB) is currently drafting the final regulations to enforce this century-long liability window.[4]

This "Perpetual Private Liability" model is designed to prevent the corporate shell games that have historically plagued the extractive industries. Environmental groups point to the thousands of orphaned oil and gas wells across the country as a cautionary tale. They warn that without strict, long-term financial assurance, a CCS operator could spin off a closed storage site into an undercapitalized subsidiary, declare bankruptcy, and leave taxpayers with the cleanup bill if the CO2 leaks.[1][2]

But capital markets view perpetual liability as a poison pill. Financiers and project developers argue that it is fundamentally impossible to underwrite a risk that never expires. The commercial insurance market currently lacks products that can cover a 100-year liability horizon, leaving developers with no clear mechanism to satisfy California’s financial assurance requirements without trapping massive amounts of capital on their balance sheets indefinitely.[2][4]

In response to this financing bottleneck, a rival regulatory framework has emerged across the Gulf Coast and the Midwest. States including Louisiana, North Dakota, Wyoming, and West Virginia have passed legislation that allows companies to transfer ownership and liability of the stored carbon to the state government.[2]

Under this "State Liability Transfer" model, the operator remains responsible during the active injection phase and for a defined post-closure monitoring period—typically 10 years. If the operator can demonstrate through seismic monitoring and pressure testing that the CO2 plume is stable and contained, the state assumes all future liability.[2][3]

To protect state budgets from catastrophic future costs, these transfer laws generally establish a publicly managed trust fund. Operators pay a per-ton fee into the fund during the active life of the project. If a leak occurs 50 years later, the state uses the pooled capital to cover remediation, re-plugging, and any associated damages.[2]

The divergence between the California model and the Gulf Coast model is already reshaping where CCS infrastructure is built. States offering liability transfer are securing the bulk of early-stage investment, as institutional capital gravitates toward regulatory certainty and capped risk. Meanwhile, California, which expects CCS to account for 25% of its net-zero emissions strategy, risks bottlenecking its own climate goals if developers cannot finance projects under the 100-year liability rule.[1][2][4]

Ultimately, policymakers are forced to choose between two imperfect trade-offs. They can accelerate the deployment of critical climate technology today by absorbing the long-term risk, or they can protect future taxpayers from potential environmental liabilities at the cost of slowing down the CCS industry. As billions of dollars in federal incentives continue to flow, the question of who owns the carbon in 2080 remains the industry's most significant unresolved variable.[6]