Enhanced Oil Recovery Market

Alberta’s in situ bitumen output, recovered almost entirely by steam, rose 6.1% to 1.95 million barrels a day in 2025, the Alberta Energy Regulator’s ST98 outlook of 29 September 2026 shows, and the One Big Beautiful Bill Act signed on 4 July 2025 lifted the US 45Q credit for carbon dioxide used in enhanced oil recovery to USD 85 a tonne, the same as geologic storage, a Clifford Chance briefing on the law states. The enhanced oil recovery (EOR) market covers spending on thermal, gas and carbon dioxide (CO2), chemical and other tertiary recovery: injectants, steam generation, chemicals, field services and dedicated equipment. Douglas Insights sizes it at USD 16.75 billion in 2025, about 3.40 million barrels a day of EOR output, or 1.24 billion barrels a year, at USD 13.50 of EOR spending a barrel, and at USD 24.86 billion in 2035, a 4.03% compound annual growth rate (CAGR). The study sits in our oil and gas equipment and services coverage, beside the Cementing Additives Market, Surfactant Market and Intelligent Pigging Technology Market reports; every figure follows the Douglas Insights research methodology.

Which EOR method earns the most: steam, CO2 injection or polymer flooding?

Thermal recovery earns the most, 52.0% of 2025 EOR spending or about USD 8.71 billion, Douglas Insights estimates, because steam lifts Canadian bitumen and heavy oil. Chemical EOR grows fastest, 6.0% a year to USD 4.50 billion by 2035.

Thermal recovery leads because it moves the largest barrels and burns the most fuel per barrel. Canadian Natural Resources produced a record 275,086 barrels a day of thermal in situ oil in 2025, its annual results of 5 March 2026 show, and California Resources runs 221 natural gas-fired steam generators with 681,000 barrels a day of steam capacity in the San Joaquin basin, its 2025 annual report states. Thermal grows 3.0% a year to USD 11.71 billion, a Douglas Insights estimate, close to the pace of new oil sands pads.

CO2 and gas injection, USD 5.03 billion, grows 4.8% on the new 45Q parity and Chinese CCUS projects. Chemical EOR, USD 2.51 billion, grows fastest at 6.0% because polymer floods cost less per barrel than steam and suit mature waterfloods in China, Oman, India and Indonesia. ONGC awarded SNF Flopam India a 10-year, INR 547 crore contract for full-field polymer injection in 38 wells at the Bechraji field in Gujarat, Chemical Weekly reported on 3 April 2026. Method values for 2035 sum to USD 25.05 billion, 0.80% above the headline.

Where is EOR applied: onshore fields or offshore reservoirs?

Onshore fields take 88.0% of 2025 EOR spending, about USD 14.74 billion, Douglas Insights estimates, because steam and CO2 pipelines are built on land. Offshore EOR grows faster, 5.6% a year to USD 3.47 billion by 2035.

Onshore dominates because every large thermal project, from Christina Lake in Alberta to Mukhaizna in Oman and Duri in Sumatra, sits on land. Indonesia’s energy ministry said first steam reached North Duri Area 14 in mid-January 2025, with all 15 injector patterns due by June 2025 and 6.74 million barrels of reserves, its release of 5 February 2025 states. Onshore spending grows 3.8% a year to USD 21.40 billion.

Offshore EOR, USD 2.01 billion, is mostly gas and CO2 reinjection on floating production units. Petrobras reinjected a record 14.2 million tonnes of CO2 in its pre-salt fields in 2024, up from 13 million, across 22 floating production units, eixos reported on 27 March 2025. Offshore grows 5.6% as new Brazilian units add separation and reinjection trains, a Douglas Insights estimate. Location values for 2035 sum to USD 24.87 billion, 0.06% above the headline.

What drives EOR demand: 45Q parity, oil sands growth or Middle East heavy oil?

EOR spending rises 4.03% a year in our base case: EOR output grows 3.2% a year to about 4.66 million barrels a day and spending per barrel rises 0.8%. Four drivers add 4.40 points to output; restraints remove 1.20.

Canadian oil sands thermal growth: 1.30 points

In situ bitumen is the largest driver, worth 1.30 points. Alberta’s total raw bitumen output is forecast to reach 4.39 million barrels a day by 2035, 18% above 2025, the AER ST98 outlook states, and Canada set a crude oil record of 5.35 million barrels a day in 2025, the Canada Energy Regulator’s snapshot of 17 June 2026 shows. Cenovus’s Christina Lake averaged 254,300 barrels a day in 2025 and 308,900 in the fourth quarter, its results of 19 February 2026 show. Douglas Insights estimates in situ steam projects add about 450,000 barrels a day by 2035.

US 45Q parity for CO2 EOR: 1.20 points

Tax parity adds 1.20 points. Under the 4 July 2025 law, carbon capture equipment placed in service after enactment earns USD 85 a tonne for CO2 used in EOR, up from USD 60, the Global CCS Institute notes. Occidental’s 2025 annual report calls CO2 EOR operations “critical to the Company’s long-term strategy”, its 10-K filed in February 2026 states, and ExxonMobil had about 16 million tonnes a year of CO2 transport and storage contracted after its Calpine deal, its release of 23 April 2025 shows. Douglas Insights estimates parity lifts captured CO2 delivered to US floods by 40% by 2032.

Middle East and North Africa heavy and mature fields: 1.10 points

Gulf fields add 1.10 points. EOR supplied 19% of Petroleum Development Oman’s crude output in 2025 against 5% in 2014 and is projected at about 28% by 2031, the Oman Observer reported from PDO’s sustainability report on 4 August 2025, with the Haima West, Nimr-A and Nimr-E polymer projects due in 2026. Occidental’s Oman unit produced 72,000 barrels of oil equivalent a day in 2025, up from 66,000, and extended the Mukhaizna steamflood licence by 15 years, the Oman Observer reported on 9 April 2026. Douglas Insights estimates Gulf EOR output rises about 300,000 barrels a day by 2035.

Chinese CCUS-EOR and chemical floods: 0.80 points

China adds the last 0.80 points. China National Petroleum Corporation’s Xinjiang Oilfield raised CO2 injection from 126,000 tonnes in 2022 to 1 million tonnes in 2025, China Daily reported on 29 December 2025, and CNPC has injected more than 13 million tonnes in total, with over 1.37 million in the first half of 2026, up 14.2%, Carbon Herald reported on 28 September 2026. Summed, 1.30 + 1.20 + 1.10 + 0.80 = 4.40 points, a Douglas Insights estimate.

What holds EOR back: oil price swings, steam emissions or project cost?

Two restraints remove 1.20 points a year from output growth: oil price swings and a forecast 2027 surplus take 0.70 points, and steam emissions and fuel cost take 0.50 points; oil-indexed CO2 contracts then cap the price leg at 0.8%.

Price swings are the heavier drag because EOR barrels cost more to lift than primary barrels and are the first to be deferred. Brent averaged USD 69.04 a barrel in 2025, jumped to USD 114 in September 2026 after attacks on Middle East oil infrastructure and is forecast at USD 83.74 in 2027, the US Energy Information Administration (EIA) Short-Term Energy Outlook of 6 October 2026 shows. The International Energy Agency (IEA) expected upstream investment to fall 6% to about USD 420 billion in 2025, its Oil 2025 report of 17 June 2025 states. Douglas Insights estimates each USD 10 a barrel fall below USD 70 delays about 5% of planned EOR phases.

Steam emissions are the second drag. Thermal projects burn natural gas to raise steam, so carbon prices and methane rules raise cost per barrel. Canada’s Spring Economic Update of 28 April 2026 proposed adding EOR to the federal carbon capture investment tax credit only at half the standard rates and only where at least 95% of CO2 stays stored, MLT Aikins explains, which helps capture but leaves steam fuel cost untouched, a Douglas Insights estimate.

Which region spends the most on enhanced oil recovery, and where does it grow fastest?

North America spends the most on EOR, USD 9.05 billion or 54.0% of 2025 spending, led by Alberta steam and Permian CO2 floods. The Middle East and Africa grow fastest, 5.4% a year to USD 6.24 billion by 2035.

North America leads because Alberta’s 1.95 million barrels a day of in situ bitumen, in the AER outlook, is the world’s largest thermal recovery base, and US CO2 floods add Permian and Rockies output. Kinder Morgan’s CO2 segment holds a 45% interest in McElmo Dome, which delivers about 1.5 billion cubic feet a day, and prices most CO2 sales off crude oil, its 2025 annual report states. North America grows 3.3% a year to USD 12.51 billion.

The Middle East and Africa, USD 3.69 billion, grow 5.4% on Omani steam and polymer and Kuwaiti heavy oil. Asia Pacific, USD 2.51 billion, grows 4.8% on Chinese CO2 and polymer floods and Indonesian steam; Pertamina Hulu Rokan planned chemical EOR injection at Minas from December 2025, adding 1,500 to 2,000 barrels a day from mid-2026, Katadata reported on 24 July 2025. Latin America, USD 1.01 billion, grows 5.0%, and Europe and Eurasia, USD 503 million, 2.6%. Regional values sum to USD 17.43 billion in 2026 and USD 25.05 billion in 2035, 0.79% above the headline.

Which companies lead enhanced oil recovery?

Cenovus Energy leads EOR spending with about 9% of 2025 market value, Douglas Insights estimates, and the five largest, Cenovus, Canadian Natural, CNPC, Occidental and Petroleum Development Oman, hold about 35% together; service and chemical suppliers share the rest.

Cenovus’s lead rests on steam-assisted gravity drainage (SAGD): Foster Creek averaged about 206,100 barrels a day in 2025 beside Christina Lake’s 254,300, its 19 February 2026 results show. Canadian Natural also runs the Pelican Lake polymer flood, which produced 42,470 barrels a day in 2025, down 5%, its 5 March 2026 results show. Douglas Insights counts operator spending on steam, injectants and EOR services, not the value of the oil produced.

Suppliers are consolidating. SLB closed its purchase of ChampionX, a production chemicals and artificial lift supplier, on 16 July 2025 and expects about USD 400 million of yearly pretax synergies within three years, its 8-K exhibit states. ExxonMobil, which bought Denbury and its more than 1,300 miles of CO2 pipeline in a USD 4.9 billion deal, its release of 2 November 2023 states, now sells CO2 transport and storage to industrial emitters along the US Gulf Coast.

Chemical capacity is moving towards fields. ZL EOR Chemicals is building a USD 300 million, 350,000 tonne-a-year polyacrylamide plant in Sohar, Oman, with a first phase targeted for early 2026, the Oman Observer reported on 10 May 2025. SNF, whose Indian arm won the ONGC contract, supplies polymer floods from Oman to India, and California Resources keeps steamfloods at Belridge and Midway-Sunset.

How much does EOR cost per barrel, from polymer floods to steam?

Enhanced oil recovery costs an average USD 13.50 of EOR-specific spending per barrel in 2025, Douglas Insights estimates, from about USD 4 for a polymer flood to USD 18 or more for steam on heavy oil.

The average blends very different methods. Douglas Insights puts EOR-specific cost at about USD 3 to USD 8 a barrel for polymer flooding, USD 8 to USD 14 for purchased CO2 and recycling, USD 10 to USD 20 for thermal recovery, where natural gas for steam is the main cost, and USD 6 to USD 12 for gas reinjection offshore. Purchased CO2 depends on oil: a US Department of Energy National Energy Technology Laboratory (NETL) study found EOR operators paying about USD 25 a tonne of CO2 at USD 70 oil, its report of 31 October 2022 states.

Spending per barrel rises 0.8% a year in the base case. Oil-indexed CO2 contracts lift it in high-price years, because Kinder Morgan and other suppliers price most sales off crude, its 2025 annual report notes. The US marginal-well and EOR credit references a 2025 crude reference price of USD 63.40 a barrel under IRS Notice 2026-30, KPMG reported on 22 May 2026. Better steam-to-oil ratios and cheaper polymer from new Omani and Chinese plants pull cost down, a Douglas Insights estimate.

Fuel is the swing input for thermal projects. Each barrel of SAGD bitumen needs about two to three barrels of water converted to steam, and gas prices in Alberta and California set most of the cost, a Douglas Insights estimate.

What if oil prices fall or CO2 supply jumps: how large is EOR in 2035?

The enhanced oil recovery market ends 2035 between USD 20.02 billion and USD 30.78 billion across our three cases, around a base of USD 24.86 billion. Oil prices and the pace of captured CO2 supply set most of the spread.

In the slower case Brent settles near USD 60 after the forecast 2027 surplus, new SAGD phases slip and few capture plants reach EOR fields, taking 1.4 points off output and 0.8 points off spending per barrel. In the faster case 45Q parity draws ethanol, gas processing and direct air capture CO2 into Permian floods, and Chinese and Omani polymer projects run on schedule, adding 1.4 points of output. One extra point of yearly growth adds about USD 2.4 billion to 2035 spending, a Douglas Insights estimate.

Live signals sit near the base case. Record Canadian output and rising CNPC injection point up, while the EIA’s falling 2027 price path and the IEA’s cautious investment view point down. Our 4.03% rate reflects steady thermal growth plus faster CO2 and chemical growth from a smaller base.

Which rules shape EOR, from 45Q and Class VI wells to Canada’s tax credit?

Three rule sets shape EOR: US 45Q credits and Class VI well permitting, Canada’s carbon capture investment tax credit and provincial rules, and national CCUS targets in China and the Gulf.

The US rules are the most detailed. The 2025 law kept 45Q at USD 85 a tonne for both storage and EOR use and USD 180 for direct air capture with prevailing wage and apprenticeship, the Global CCS Institute notes, while IRS Notice 2026-29 set the 45Q inflation factor at 1.4639, KPMG reported. The Environmental Protection Agency granted Texas primacy over Class VI CO2 storage wells on 12 November 2025, FactSet reported, bringing state-run permitting to six states; EOR wells themselves remain Class II.

Canada and China add their own incentives. The federal proposal of 28 April 2026 covers EOR spending from that date to 2035 in designated provinces, at 30% for direct air capture, 25% for other capture and 18.75% for transport, storage and use, BNN Bloomberg reported. China targets about 10 million tonnes a year of CCUS capacity in 2026 to 2030, China Daily reported from CNPC on 29 December 2025, most of it tied to oilfield injection.

Douglas Exclusive: the Tertiary Barrel Ledger

The Tertiary Barrel Ledger is a Douglas Insights model built from 12 inputs: 7 company filings and releases and 5 government or regulatory texts, listed below. It tracks how much oil depends on injected steam, gas or chemicals.

The finding, a Douglas Insights estimate: EOR output of about 3.40 million barrels a day was about 3.2% of world liquids supply in 2025 and rises to about 4.3% by 2035, because mature fields in Oman, China and the US rely more on injection while primary output from those fields declines.

The ledger changes how to read upstream spending. A cut in total upstream investment, such as the 6% fall the IEA expected for 2025, hits new exploration first and EOR last, because EOR adds barrels to fields that already have wells, pipes and processing. Douglas Insights therefore weights operating EOR output more heavily than capital budgets in the forecast.

How does the methodology turn 3.40 million barrels a day into USD 16.75 billion?

Our methodology multiplies about 1.24 billion EOR barrels in 2025, 3.40 million barrels a day, by EOR-specific spending of USD 13.50 a barrel to reach USD 16.75 billion, then grows output 3.2% and spending per barrel 0.8% a year.

The model covers 4 recovery methods, 2 locations and 5 regions, using 64 data points, 24 sourced and 40 modelled. The output base comes from regulator and company disclosures, such as Alberta’s 1.95 million barrels a day of in situ bitumen and PDO’s 19% EOR share, plus Douglas Insights estimates for US CO2 floods and Chinese polymer floods; spending per barrel comes from filings and the NETL cost study. Arithmetic: 1.241 billion barrels x USD 13.50 = USD 16.75 billion; USD 16.75 billion x (1.032 x 1.008)^10 = USD 24.86 billion. Output reaches about 4.66 million barrels a day in 2035.

Two cross-checks agree. First, the estimated EOR spending of Cenovus, Canadian Natural, CNPC, Occidental and PDO sums to about USD 5.9 billion, about 35% of our total, matching our top-five share. Second, the US Geological Survey puts technically recoverable CO2-EOR oil in the United States at a mean 29 billion barrels, its assessment of 1 December 2022 states, enough to support our US growth path for decades. AI tools help draft the text and automated checks test the arithmetic and links; the Douglas Insights research desk chooses the sources, builds the model and approves publication, as our editorial standards explain.

Sources

1. Alberta Energy Regulator ST98: Alberta energy outlook 2026 (2026)
2. Clifford Chance One Big Beautiful Bill Act: updates to Section 45Q (2025)
3. Canadian Natural via SEC Canadian Natural 2025 fourth quarter and annual results (2026)
4. California Resources via SEC California Resources 2025 Form 10-K (2026)
5. Chemical Weekly SNF Flopam India bags ONGC Bechraji polymer injection project (2026)
6. Ministry of Energy and Mineral Resources, Indonesia Minister visits Rokan Block (2025)
7. eixos Petrobras sets record for CO2 injection (2025)
8. Canada Energy Regulator Canada sets new record in crude oil production in 2025 (2026)
9. Cenovus via SEC Cenovus 2025 fourth quarter and full-year results (2026)
10. Global CCS Institute U.S. preserves and increases 45Q credit (2025)
11. Occidental via SEC Occidental 2025 Form 10-K (2026)
12. ExxonMobil Calpine and ExxonMobil sign CO2 transportation and storage agreement (2025)
13. Oman Observer EOR share of PDO's crude oil output to reach 28% by 2031 (2025)
14. Oman Observer Oxy Oman posts 9% growth in hydrocarbon production (2026)
15. China Daily Xinjiang Oilfield CO2 injection reaches 1 million tonnes (2025)
16. Carbon Herald CNPC injects over 13 million tons of CO2 (2026)
17. US EIA Short-Term Energy Outlook, October 2026 (2026)
18. IEA Oil 2025: executive summary (2025)
19. MLT Aikins Canada expands CCUS investment tax credit to include EOR (2026)
20. Kinder Morgan via SEC Kinder Morgan 2025 Form 10-K (2026)
21. Katadata Pertamina Hulu Rokan CEOR injection in December (2025)
22. SLB via SEC SLB completes acquisition of ChampionX (2025)
23. ExxonMobil ExxonMobil completes acquisition of Denbury (2023)
24. Oman Observer Oman's biggest polymer project set for Q1 2026 launch (2025)
25. US DOE NETL CO2-EOR economics study DOE/NETL-2023/3817 (2022)
26. KPMG IRS notices on 45Q inflation adjustment and EOR reference price (2026)
27. FactSet Class VI primacy update: Texas moves forward (2025)
28. BNN Bloomberg Feds formalize EOR tax credit in Spring Economic Update (2026)
29. USGS Assessment of CO2 enhanced oil recovery and associated CO2 retention (2022)

What counts in the enhanced oil recovery study, and what is excluded?

The enhanced oil recovery study counts spending on thermal, gas and CO2, chemical and other tertiary recovery worldwide: injectants, steam generation, EOR chemicals, field services and dedicated equipment. Waterflooding, oil sands mining and the value of oil produced are excluded.

The study splits spending by 4 recovery methods, 2 locations and 5 regions: North America, the Middle East and Africa, Asia Pacific, Latin America, and Europe and Eurasia. Surfactant chemistry is sized in our Surfactant Market report and well cement chemicals in the Cementing Additives Market report.