Mineral Rights Guide 2026
EOR operations extend field life by decades, create new production peaks, and fundamentally change how mineral rights are valued. From Mississippi's CO2 floods to the Permian Basin's massive tertiary recovery programs, EOR fields represent some of the most stable mineral ownership opportunities in the country.
Enhanced Oil Recovery (EOR), also called tertiary recovery, refers to techniques that extract oil remaining in a reservoir after primary production (natural pressure) and secondary recovery (waterflooding) have been exhausted. Conventional methods typically recover only 20-40% of original oil in place (OOIP), while EOR can unlock an additional 10-20%.
The most common EOR method in the U.S. Carbon dioxide is injected into the reservoir at pressures above its minimum miscibility pressure (MMP), where it dissolves into the crude oil, reducing viscosity and swelling the oil so it flows more freely toward production wells. CO2 can come from natural sources like Jackson Dome in Mississippi or from industrial capture facilities.
The oldest and most widespread secondary/tertiary recovery method. Water is injected into the formation to maintain reservoir pressure and sweep oil toward production wells. Advanced techniques include polymer-augmented waterflooding and low-salinity flooding, which can improve sweep efficiency by 5-15% beyond conventional waterfloods.
Involves injecting surfactants, polymers, or alkaline solutions to reduce the surface tension between oil and rock, allowing trapped oil to be mobilized. Chemical EOR is typically used in sandstone reservoirs with medium-viscosity crude. While effective, the cost of chemical agents limits widespread adoption compared to CO2 methods.
Steam is injected into the reservoir to heat heavy, viscous crude oil, reducing its viscosity so it can flow to production wells. Steam-assisted gravity drainage (SAGD) and cyclic steam stimulation (CSS or "huff and puff") are the primary thermal methods. Most common in California's heavy oil fields and Canadian oil sands.
Mississippi is the undisputed national leader in CO2-based enhanced oil recovery, thanks to a unique natural advantage: the Jackson Dome, a massive underground reservoir of naturally occurring CO2 located near Jackson, Mississippi.
The Jackson Dome is a subsurface volcanic structure that produces nearly pure CO2 gas. This natural CO2 source eliminates the need for costly industrial capture, giving Mississippi operators a significant economic advantage. The CO2 is transported through a 925-mile pipeline network that connects the source to oil fields across central and southern Mississippi.
County: Yazoo County
Formation: Lower Tuscaloosa
One of the largest CO2 flood projects in Mississippi, Tinsley has produced significant volumes through tertiary recovery since the 1980s. The field demonstrates how EOR can revitalize production decades after primary recovery.
County: Jasper County
Formation: Eutaw Formation
Heidelberg is a major CO2 flood operation producing from the Eutaw Formation. The field has seen substantial production increases since tertiary operations began, with consistent output over multiple decades.
County: Lincoln County
Formation: Lower Tuscaloosa
A pioneer CO2 flood field that has been under tertiary recovery for decades. Little Creek serves as a benchmark for CO2 EOR performance in Mississippi's Lower Tuscaloosa sandstone reservoirs.
County: Adams County
Formation: Lower Tuscaloosa
Cranfield has been both an active EOR field and a major CO2 sequestration research site. The U.S. Department of Energy has used Cranfield for extensive CCUS monitoring and verification studies.
County: Lincoln County
Formation: Lower Tuscaloosa
These adjacent fields in Lincoln County have been under CO2 flood operations, contributing to the dense cluster of EOR activity in southwestern Mississippi.
County: Pike County
Formation: Lower Tuscaloosa
Located in the southern portion of Mississippi's EOR corridor, McComb has benefited from proximity to the Jackson Dome CO2 pipeline network.
In 2023, ExxonMobil completed its $4.9 billion acquisition of Denbury Resources, gaining control of Mississippi's entire CO2 EOR infrastructure. This includes the 925-mile CO2 pipeline network, Jackson Dome CO2 source rights, and all of the fields listed above. ExxonMobil's investment signals long-term commitment to Mississippi EOR operations and positions the company for expanded CCUS activities using its existing pipeline and injection infrastructure.
For a deeper look at Mississippi's EOR and CCUS landscape, visit our Mississippi EOR & CCUS Basin Guide.
Texas hosts the largest volume of EOR production in the United States, concentrated in the Permian Basin of West Texas. CO2 is sourced primarily from natural deposits at McElmo Dome and Sheep Mountain in Colorado, transported via Kinder Morgan's extensive pipeline network.
SACROC Unit (Scurry County): One of the first large-scale CO2 floods in the world, operating since the 1970s. SACROC produces from the Canyon Reef formation and remains a major tertiary recovery operation.
Wasson Field (Yoakum & Gaines Counties): A massive CO2 flood covering multiple units in the San Andres formation. Oxy (Occidental Petroleum) operates the Denver Unit and other sections of this prolific field.
Seminole Unit (Gaines County): Another large-scale Permian CO2 flood producing from the San Andres formation, operated by various companies over its long production history.
Salt Creek Field (Kent County): A significant CO2 flood in the eastern Permian Basin, producing from the Canyon Reef formation with decades of remaining tertiary life.
Means Field (Andrews County): A San Andres CO2 flood in the heart of the Permian Basin.
North Ward Estes (Ward County): An active CO2 flood in the Delaware Basin side of the Permian, demonstrating the geographic breadth of Texas EOR operations.
Occidental Petroleum (Oxy) is the largest CO2 EOR operator in the Permian Basin and arguably in the world. Oxy operates dozens of CO2 flood units across West Texas, with deep expertise in reservoir management and CO2 recycling. Their operations produce hundreds of thousands of barrels per day through tertiary recovery methods.
Oxy is also investing heavily in Direct Air Capture (DAC) technology through its 1PointFive subsidiary, which could provide new sources of CO2 for EOR operations while generating carbon credits.
Kinder Morgan operates the largest CO2 transportation network in North America, moving approximately 1.3 billion cubic feet per day of CO2 from natural sources at McElmo Dome and Doe Canyon in southwestern Colorado through over 1,500 miles of pipeline to Permian Basin EOR fields in West Texas. This infrastructure is critical to the economic viability of Permian Basin CO2 floods.
East Texas also has select EOR operations, though on a smaller scale than the Permian. For more on Texas mineral rights, see our Texas Mineral Rights Guide.
Wyoming has a long history of EOR operations, particularly in the Big Horn Basin and the Powder River Basin region.
County: Natrona County
One of Wyoming's most storied oil fields, Salt Creek has been under various forms of enhanced recovery for decades. Located north of Casper, the field produces from multiple formations and has been a testing ground for CO2 and other EOR techniques.
Counties: Big Horn, Park, Washakie
The Big Horn Basin in northwestern Wyoming hosts several EOR projects, including CO2 and thermal operations. Fields like Elk Basin and Oregon Basin have long production histories enhanced by tertiary recovery programs.
Learn more about Wyoming mineral ownership in our Wyoming Mineral Rights Guide.
Oklahoma and Kansas have smaller-scale EOR operations compared to Mississippi and Texas, but they remain relevant for mineral owners in those states.
Oklahoma: Select waterflood and CO2 pilot projects operate in mature fields across the Anadarko Basin and the Sooner Trend. Oklahoma's long production history means many fields are candidates for EOR, though full-scale CO2 flooding is less common than in the Permian or Mississippi.
Kansas: Kansas has active waterflood operations in mature fields, particularly in the central Kansas uplift and Hugoton area. Some operators have experimented with CO2 and chemical floods, though at smaller scale. The state's shallow, mature reservoirs are well-suited for continued secondary and tertiary recovery.
Carbon Capture, Utilization, and Storage (CCUS) is creating new economic incentives for EOR operations and expanding the footprint of tertiary recovery across the United States.
Traditionally, EOR operators purchased CO2 from natural sources. CCUS changes this dynamic by providing industrially captured CO2 from power plants, ethanol facilities, and manufacturing operations. This creates a dual revenue stream: operators receive payment for storing CO2 (via 45Q tax credits, currently $60 per ton for EOR use and $85 per ton for dedicated geological storage) while also producing additional oil.
45Q Tax Credits: Federal incentives that pay operators per ton of CO2 permanently stored underground, whether through EOR or dedicated sequestration
New CO2 Sources: Industrial capture projects are providing CO2 in regions where natural sources are unavailable, opening new areas to EOR
Pore Space Value: The subsurface formations used for CO2 storage have independent value, which may affect mineral and surface rights depending on state law
Extended Operations: CCUS economics can justify continued EOR operations even at lower oil prices, extending royalty payments for mineral owners
As CCUS expands, pore space rights (the right to use subsurface formations for CO2 storage) are becoming increasingly valuable. In most states, pore space rights belong to the surface owner, not the mineral owner. However, active mineral rights may affect how and where CO2 can be stored. This is an evolving area of law that mineral owners in EOR areas should monitor.
EOR operations typically extend a field's productive life by 20-30 years beyond what primary and secondary recovery would deliver. This dramatically increases the net present value of future royalty streams, as mineral owners continue receiving income from fields that would otherwise be approaching abandonment.
When EOR operations begin in a mature field, production often increases significantly before settling into a long, gradual decline. This secondary peak can produce volumes approaching or exceeding the field's original primary production rates, creating a renewed revenue stream for mineral owners.
EOR requires substantial capital investment in CO2 pipelines, injection facilities, recycling plants, and monitoring equipment. When an operator commits this level of infrastructure spending, it signals a long-term commitment to the field. Mineral owners benefit because the operator is economically incentivized to maximize production over decades to recover their investment.
As CO2 storage becomes a standalone business alongside EOR, the subsurface formations gain value beyond oil production. Mineral owners in EOR areas should understand how pore space rights interact with their mineral interests, as state regulations continue to evolve around carbon storage rights and obligations.
Mineral rights in active EOR fields carry unique characteristics that many owners find compelling reasons to sell:
Peak Valuations: Active EOR operations with proven production and long reserve life can support strong purchase prices today
Commodity Price Uncertainty: Oil prices fluctuate, but a lump-sum payment locks in value regardless of future price movements
Operational Decisions You Cannot Control: An operator may change EOR patterns, reduce injection rates, or shift investment to other fields, all of which affect your royalties without your input
Regulatory Evolution: Changing rules around CO2 storage, pore space, and unitization orders may create uncertainty for mineral owners
Estate Simplification: EOR minerals held across multiple units and formations can be complex for heirs to manage
Buckhead Energy acquires mineral rights in EOR fields across Mississippi, Texas, Wyoming, and beyond. We understand tertiary recovery economics and offer:
Valuations that account for EOR production profiles
Experience with unitized interests and complex ownership
30-45 day closings
No fees or commissions
Deep dive into Mississippi's CO2 flooding operations and carbon storage opportunities.
Complete guide to mineral rights in Texas, including Permian Basin operations.
Wyoming mineral ownership guide covering the Powder River and Big Horn basins.
2026 market report for Permian Basin mineral rights.
How mineral rights are valued and what drives pricing.
Browse all mineral rights guides and educational content.
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Disclaimer: This information is for educational purposes only and does not constitute legal, financial, or tax advice. Mineral rights values vary based on property characteristics and market conditions. Consult qualified professionals before making decisions.