US CO2 storage maps flag vast acreage but leave developers short on site-level data
Federal storage assessments count broad sedimentary formations as prospective without resolving the geology needed to commit capital to a specific injection site.
Federal and state assessments mapping potential US carbon dioxide storage remain too coarse to support investment decisions, according to reporting published in August 2026, which underscores a widening gap between government claims about storage capacity and what project developers actually need to commit capital.5
The criticism arrives as the US carbon capture pipeline moves past the demonstration phase into site selection and permitting. Storage resource assessments have traditionally been produced at regional or basin scale, with the Department of Energy publishing estimates that count vast sedimentary formations as prospective storage without resolving the geological detail needed to de-risk a specific injection site.5
The technical case for carbon capture was never the binding constraint. Questions about whether solvents can strip CO2 from flue gas, whether the gas can be compressed and transported, and whether storage will remain secure over decades are increasingly well answered. The harder question is where, precisely, a given project can inject volumes at rates that make economic sense.5
Developers are finding that regional maps showing prospective storage do not translate into bankable pore space. Site-specific characterization requires seismic surveys, well data and pressure modelling that few assessments provide. A formation that appears in a national map as a broad green swath may in practice contain faulting, compartmentalization or pressure barriers that limit injectivity.5
The report echoes concerns regulators have begun to address elsewhere. The UK's North Sea Transition Authority in late July (2026-07-30) announced what it called a significant boost for the carbon storage industry, with new work aimed at unlocking the CO2 storage potential of existing oil and gas assets. DNV, which supported the NSTA effort, pointed to the potential to reduce capital expenditure and shorten project timelines for emerging CCUS value chains.4
That approach — prioritizing known reservoirs with production history over uncharacterized greenfield acreage — reflects a broader recognition that storage assessments must carry engineering confidence, not just geological presence. Legacy fields offer well data, pressure history and existing infrastructure, all of which cut the cost and time of appraisal.4
The US picture is complicated by the patchwork of pore space ownership and the division of regulatory authority between state and federal agencies. Even where the geology is promising, developers face uncertainty over who holds the right to inject, and under what rules.5
Similar barriers have already shaped outcomes abroad. India should build a national CO2 transport network alongside its existing natural gas pipelines to overcome land acquisition hurdles and boost carbon capture deployment, a study argued in May (2026-05-28). The land-access problem is not unique to any one jurisdiction, but it compounds storage uncertainty where prospective acreage is mapped without reference to surface use or pipeline corridors.1
Cross-border regulatory gaps are also unresolved. EU-UK projects are stalling in part because legal recognition of the transport and storage of captured CO2 is lacking, according to the UK trade body the Carbon Capture and Storage Association, which in June (2026-06-03) urged both sides to clarify their ETS and CO2 legal frameworks. If two adjacent regulators with mature carbon markets cannot agree on recognition, the hurdles facing site-specific investment across numerous US state jurisdictions are considerably higher.2
Carbon price signals do not yet compensate for the risk. ICE EUA Dec-rolling prices posted a 4.6% weekly loss in early June (2026-06-05), their first weekly decline since the start of May, with the market posting only a modest 0.2% decline on Friday (2026-06-05) as macro weakness weighed. A weak carbon price reduces the revenue case for capture projects and tightens the economics that any storage investment must support.3
The US has no federal carbon price to anchor project returns, leaving developers to lean on the 45Q tax credit and voluntary offtakes. One large US bank signed its second carbon removal deal with a bio-oil developer in early June (2026-06-05), bringing its total commitment with the company to 90,000 tonnes. Those offtakes help de-risk demand, but they do not address the geological uncertainty embedded in storage site selection.3
What the market needs from government is not broader maps but sharper ones. Federal agencies have yet to publish storage assessments at the scale of individual structures or reservoirs, with seismic and pressure data attached — leaving that work to developers who must fund it project by project. Until that changes, priced-in geological risk will weigh on every early-stage CCUS deal seeking financing.5