Carbon Capture Timeline 1972–2026: CCS, Direct Air Capture and the Race to Store CO₂ Underground
Carbon capture timeline from 1972 CO2 injection and Sleipner to CCS hubs, direct air capture, offshore CO2 storage and Europe's largest 2026 capture plant.
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Carbon capture sounds almost too neat: take the carbon dioxide from a factory, compress it, move it away, and lock it deep underground. After decades of experiments, engineers have shown that CO₂ can be captured and stored in geological formations. But in 2026, the hard question is no longer whether the technology can work. It is whether carbon capture can become large, cheap, safe and fast enough to matter in the climate fight. This carbon capture timeline follows the idea from 1972, when CO₂ was first injected into Texas oil fields, through Norway’s Sleipner project, the rise of direct air capture, shared CO₂ storage hubs, and Europe’s largest carbon-capture facility, which opened at Yara Sluiskil in the Netherlands in 2026.
Can We Bury Our Carbon Problem?
🧠 Quick Answer
Carbon capture is a set of technologies that capture CO₂ before or after it enters the atmosphere. CCS captures CO₂ from concentrated industrial sources and stores it underground. Direct air capture removes CO₂ already mixed into the air. Carbon capture can help reduce emissions from difficult industries, but it faces major challenges around cost, energy use, transport, storage capacity, monitoring and scale.
Carbon Capture: Key Questions
What this carbon capture timeline really shows
- Carbon capture is not one technology. CCS at a smokestack and direct air capture from ambient air solve different problems and carry very different energy and cost profiles.
- Geological CO₂ storage has decades of track record at Sleipner, Weyburn and In Salah, but scaling it from tens of millions to billions of tonnes a year worldwide remains unproven.
- CCS is most defensible for hard-to-decarbonise industries such as cement, chemicals, steel and fertiliser, where there is no easy switch to electricity.
- Critics worry CCS becomes an excuse to keep burning fossil fuels, and point to slow deployment, high energy penalties and long-term monitoring duties.
- The 2026 Netherlands project matters because it links industrial capture at Yara Sluiskil to cross-border offshore storage by Northern Lights, the first full chain of its kind in operation.
- Carbon capture has to be judged on real numbers: annual tonnes captured, energy used, monitoring commitments and emissions actually avoided, not on announced capacity.
Where Does the CO₂ Go?
Carbon capture does not make emissions vanish. It changes the path of CO₂ from atmosphere to monitored storage.
CCS and DAC Are Not the Same Thing
Related tools, different jobs — and the distinction matters for what each can honestly claim
The Industries CCS Is Really Aimed At
Sectors where switching to electricity is hard, because the CO₂ comes from chemistry or extreme heat, not just fuel choice
Cement
Around half of cement’s CO₂ comes from the chemical reaction that turns limestone into clinker, not from the kiln fuel, so cleaner power alone does not fix it.
Steel
Traditional blast furnaces use coke as both fuel and chemical reductant. Hydrogen routes exist but are early; CCS is one bridge for existing plants.
Chemicals
Many processes need high-temperature heat and produce concentrated CO₂ streams as a by-product, which makes capture technically easier here than almost anywhere else.
Fertiliser
Ammonia plants emit a nearly pure CO₂ stream during hydrogen production. Yara’s Sluiskil project captures exactly this stream.
Waste-to-energy
Municipal waste incinerators burn a mix that is impossible to fully decarbonise at source, so capture is one of the few options for deep cuts.
Fossil power
CCS on coal and gas plants is where critics push back hardest, arguing the money and years are better spent on renewables, grids and storage.
Timeline: From Oilfield Injection to Cross-Border Storage, 1972–2030
Newest developments first. Where a project spans years, the entry marks the moment it changed the picture.
Carbon capture did not arrive as a single breakthrough. It grew out of oil-and-gas engineering, was picked up by climate policy, stumbled badly in the power sector, quietly proved itself in industry, and is now being rebuilt as shared infrastructure. Reading the sequence in order shows why the 2026 Yara Sluiskil opening is a milestone and not a beginning.
Can CCS Scale Enough to Matter?
What is at stake: Engineers can store CO₂. The unresolved question is whether it can be done at the scale climate models assume. Based on today’s project pipeline the IEA sees capture capacity reaching roughly 430 million tonnes a year by 2030 if everything announced is built, still a small share of global emissions and dependent on subsidies, permits and pipelines arriving on time.
Why it matters: The climate payoff depends less on the chemistry and more on price, permanence, regulation, public trust, and whether CCS is reserved for genuinely hard-to-abate emissions rather than used to prolong fossil-fuel demand.
Yara Sluiskil Opens Europe’s Largest Carbon-Capture Facility
What happened: Fertiliser maker Yara inaugurated what Reuters described as Europe’s largest industrial carbon-capture facility at its ammonia plant in Sluiskil. From 2026 the plant will capture and liquefy up to 800,000 tonnes of CO₂ a year. The chain runs from ammonia production, to CO₂ capture and liquefaction, to ship transport, to storage about 2.6 km beneath the seabed on the Norwegian continental shelf by Northern Lights. Yara expects to remove roughly 12 million tonnes over 15 years.
Why it matters: This is the fresh trigger for revisiting the whole timeline. It is the first industrial-scale capture project wired into a cross-border commercial storage service, rather than a one-off site storing its own CO₂ next door. The prime ministers of Norway and the Netherlands and the EU climate commissioner attended, a signal of how central governments now consider this chain.
Northern Lights Stores Its First CO₂
What happened: The Northern Lights joint venture, part of Norway’s state-backed Longship programme, received its first CO₂ by ship from a cement plant at Brevik and injected it into a reservoir about 2,600 m below the seabed. Phase one offers 1.5 million tonnes a year of storage, fully booked by Norwegian and European customers. A second phase, sanctioned in 2025, is designed to lift capacity above 5 million tonnes a year from 2028.
Why it matters: It created something new: a third-party CO₂ storage service that industrial emitters elsewhere in Europe can buy into, which is the piece the Yara chain plugs into a year later.
Porthos Begins Construction Under the North Sea
What happened: Porthos, a joint venture of Dutch state energy firm EBN, gas network operator Gasunie and the Port of Rotterdam, started building a shared CO₂ pipeline and offshore injection system. It is designed to take about 2.5 million tonnes of CO₂ a year from Air Liquide, Air Products, ExxonMobil and Shell in the port and store it in depleted gas fields roughly 3 to 4 km beneath the North Sea, around 20 km offshore, for a total near 37 million tonnes over 15 years. Investment is put at about 1.3 billion euro.
Why it matters: Porthos is the clearest example of the shift from single-plant projects to shared hubs: one piece of infrastructure serving several factories at once, which is how CCS advocates argue costs finally come down.
Big Subsidies Arrive, and India Publishes Its First CCUS Policy
What happened: The US Inflation Reduction Act raised the 45Q tax credit to as much as 85 dollars per tonne for stored industrial CO₂ and 180 dollars per tonne for direct air capture, triggering a wave of announced projects along the Gulf Coast. In the same period NITI Aayog, India’s central policy think tank, released a Carbon Capture, Utilisation and Storage policy framework aimed at steel, cement, chemicals and refineries, sectors central to India’s 2070 net-zero target.
Why it matters: For years the barrier to CCS was not physics but economics. These moves tried to fix the incentive gap, and much of the current project pipeline dates from this shift.
CCS Hubs and Shared CO₂ Networks Expand
What happened: Planning shifted from isolated capture-and-store projects to clustered infrastructure: several factories in an industrial zone connected to a common CO₂ pipeline, shipping terminal and storage site. Rotterdam, the UK’s east coast, Norway and the US Gulf Coast all advanced versions of this model.
Why it matters: Shared transport and storage spreads fixed costs across many emitters and is the main route by which supporters expect CCS to move from demonstration to routine industrial service.
Direct Air Capture Becomes Commercial
What happened: Swiss company Climeworks opened what it billed as the first commercial direct air capture plant, pulling CO₂ from ambient air and selling it to a nearby greenhouse. Later plants in Iceland paired DAC with mineral storage underground.
Why it matters: DAC is a different category from CCS. It removes CO₂ that is already in the atmosphere rather than catching a concentrated industrial stream, but because outdoor air is only about 0.04 percent CO₂ it is far more energy-intensive per tonne, and remains small and expensive.
The Paris Agreement Raises the Bar for Deep Decarbonisation
What happened: Nearly every country agreed to hold warming well below 2 degrees Celsius and to pursue 1.5 degrees. Most modelled pathways to those goals assume some carbon capture and some carbon removal, precisely because a few sectors are hard to electrify or clean up quickly.
Why it matters: Paris renewed institutional interest in CCS after a decade of disappointments, and framed it as a tool for the last, most stubborn slice of emissions rather than a licence for business as usual.
Boundary Dam: First Commercial CCS on a Coal Power Plant
What happened: SaskPower retrofitted Unit 3 of its Boundary Dam coal station with post-combustion capture designed for roughly 1 million tonnes of CO₂ a year, most of it sold for enhanced oil recovery with some going to saline storage.
Why it matters: It proved capture could run on a working power plant, and it exposed the problem: high capital cost, an energy penalty that cuts plant output, and early reliability issues. Later power-sector CCS plans in the US and UK were cancelled or delayed on similar economics.
Power-Sector CCS Stumbles, Industrial Storage Proves Itself
What happened: CCS was heavily promoted for coal and gas power because it promised lower emissions without shutting plants immediately. Many flagship power projects became too expensive or were abandoned. In parallel, industrial and gas-processing projects such as In Salah in Algeria and the Weyburn-Midale monitoring study in Canada showed that capture, transport and deep storage could work and could be measured for leaks.
Why it matters: This split still shapes the debate. The technology’s credible track record is in industry and gas processing, not in cleaning up power stations, which is where most public scepticism sits.
The IPCC Puts CCS on the Climate Map
What happened: The Intergovernmental Panel on Climate Change published a dedicated special report assessing capture methods, pipeline safety, storage security and cost. It concluded that deep geological storage could retain the large majority of injected CO₂ over very long timescales if sites were well chosen and monitored.
Why it matters: It moved carbon capture from a petroleum-industry technique into mainstream climate policy language, and set the terms, evidence levels and cost models that governments still use.
Norway’s Sleipner Begins Storing CO₂ Under the North Sea
What happened: Natural gas from the Sleipner field contained too much CO₂ to sell, so operator Statoil, now Equinor, separated it and, instead of venting it, injected roughly 1 million tonnes a year into the Utsira sandstone, a saline formation about 800 to 1,000 m below the seabed. Norway’s 1991 CO₂ tax made storage cheaper than paying to emit.
Why it matters: Sleipner is the first climate-relevant, dedicated offshore CO₂ storage project, and decades of seismic surveys tracking the CO₂ plume underground remain a core piece of evidence that geological storage can hold.
CO₂ Injection Begins in Texas Oil Fields
What happened: Gas-processing plants in West Texas began separating CO₂ from natural gas and piping it to ageing oil fields, where it was injected to push out more crude, a practice called enhanced oil recovery. This was decades before climate policy treated buried carbon as a public issue.
Why it matters: Much of the CCS industry’s early engineering, from compression to pipelines to injection wells, comes straight from this oil-and-gas work. That heritage is also why critics are wary: the same tools can serve either climate storage or more oil production.
Supporters vs Critics
Carbon capture is promising, complicated and contested at the same time — both cases below are held by serious people
These are not mutually exclusive. A common middle position is that CCS is worth public money for genuinely hard-to-abate industry and for a limited amount of carbon removal, but is a poor substitute for cutting fossil-fuel use, building renewables and grids, improving efficiency and reducing methane.
Major CO₂ Storage Milestones at a Glance
Selected projects that shaped what is known about capturing and storing carbon
| Year | Project | Location | What it showed |
|---|---|---|---|
| 1972 | Val Verde / Permian Basin EOR | Texas, USA | CO₂ could be separated and injected at scale, for oil recovery |
| 1996 | Sleipner | Norwegian North Sea | First dedicated offshore storage in a saline aquifer, driven by a carbon tax |
| 2004 | In Salah | Algeria | Onshore storage from gas processing, with detailed subsurface monitoring |
| 2000s | Weyburn-Midale monitoring study | Saskatchewan, Canada | Multi-year international measurement of an injected CO₂ plume for leaks |
| 2014 | Boundary Dam Unit 3 | Saskatchewan, Canada | First commercial capture on a coal power plant, and its cost problems |
| 2017 | Climeworks Hinwil | Switzerland | First commercial direct air capture, small and energy-hungry |
| 2025 | Northern Lights phase 1 | Norwegian shelf | First third-party CO₂ storage service, sold to outside emitters |
| 2026 | Yara Sluiskil | Netherlands | Europe’s largest capture plant, feeding cross-border offshore storage |
Facts Worth Knowing
- The first large-scale CO₂ capture was not for the climate at all — it was 1970s Texas gas processing, with the CO₂ used to squeeze more oil out of old fields.
- Sleipner has been injecting about a million tonnes of CO₂ a year since 1996, and the plume has been tracked by repeated seismic surveys ever since.
- Direct air capture and point-source CCS are often lumped together, but ambient air is roughly 0.04 percent CO₂, so DAC moves far more air and uses far more energy per tonne.
- As of 2026 the world captures on the order of 50 million tonnes of CO₂ a year, against annual emissions in the tens of billions of tonnes.
- The Yara Sluiskil to Northern Lights chain crosses two borders: a Dutch fertiliser plant’s CO₂ is shipped to Norway and stored under the North Sea.
- No credible operator calls a storage site permanently safe without qualification — the standard is well-chosen geology plus long-term monitoring and clear liability.
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⚠️ Editorial & Sources Note
Author: The AI Timeline Editorial Team · Last updated: 8 September 2026. This article does not claim carbon capture makes emissions or pollution disappear, that captured CO₂ is permanently safe without monitoring and well-chosen geology, or that CCS can replace cutting emissions. Point-source capture avoids emissions; direct air capture can remove CO₂ already in the air, and the two are not interchangeable. Capacity figures are given as annual tonnes with their source. The 2026 Yara Sluiskil figures and framing follow Reuters reporting; global capacity and 2030 projections follow the IEA; storage-security statements follow the IPCC and project operators. This is editorial coverage of climate technology, not investment, engineering or policy advice.