If you own mineral rights in South or Southwest Texas — whether you inherited them from a grandparent or bought land decades ago — there's a good chance those rights sit over one of the most productive shale formations in the United States. The Eagle Ford Shale has generated hundreds of billions of dollars in oil and gas revenue since it was first developed commercially around 2009. That doesn't mean every acre is equally valuable, but it does mean your rights are worth understanding before you decide what to do with them.
This article will walk you through how the Eagle Ford works, which counties and zones are producing the most right now, who the major operators are, what your royalties might look like, and what the current market means for mineral owners who are thinking about selling. By the end, you'll have a clearer picture of what you actually own and what realistic options look like in today's market.
You don't need a geology degree or an oil and gas background to understand this. The concepts aren't complicated once someone explains them plainly — and that's exactly what we're going to do here.
What the Eagle Ford Actually Is and Why Location Within It Matters So Much
The Eagle Ford Shale is a geological formation — a layer of ancient marine rock containing oil, gas, and a liquid called condensate — that stretches roughly 400 miles across South Texas in a narrow band running from the Mexican border near Laredo northeast through San Antonio and toward East Texas. The formation sits roughly 4,000 to 14,000 feet underground depending on where you are.
Here's the most important thing to understand about the Eagle Ford: your exact location within the formation largely determines what type of hydrocarbons are beneath your land, and that directly affects value. Geologists divide the Eagle Ford into three general windows or zones based on depth and temperature:
- The Oil Window runs through counties like Karnes, DeWitt, Gonzales, and Wilson. This zone produces primarily crude oil, which is the most valuable product per barrel. Wells in this window are typically the most aggressively drilled and most sought-after by operators.
- The Condensate Window sits just to the southwest and includes parts of Dimmit and La Salle counties. This zone produces a light liquid hydrocarbon called condensate, along with natural gas. Condensate is valuable but prices it at a discount to crude oil.
- The Dry Gas Window is the deepest and hottest zone, extending further southwest toward Webb County and Laredo. It produces natural gas almost exclusively. Gas prices have been low for several years, which has made this window less active for new drilling, though it's not without value.
If your mineral rights are in Karnes or DeWitt County, you are almost certainly in the heart of the oil window, and that matters enormously. Karnes County alone has some of the highest initial production rates — the amount of oil a well pumps in its first 30 to 90 days — in the entire Eagle Ford play. DeWitt County sits right next to it and has seen similar performance. These two counties regularly rank among the top producing Eagle Ford counties in Texas Railroad Commission data.
If you're not sure which window your acreage falls in, a quick look at the Texas Railroad Commission's GIS viewer (available free at rrc.texas.gov) can show you nearby permitted and producing wells. Or call a mineral rights buyer — a reputable one will tell you honestly which zone you're in before any conversation about pricing.
Current Production and Who's Operating in Eagle Ford Today
The Eagle Ford peaked in production around 2015, when operators were drilling aggressively with oil prices above $80 per barrel. The 2015-2016 oil price crash slowed activity significantly, and the COVID pandemic caused another sharp pullback in 2020. But the play never died — it adapted.
As of 2024, Eagle Ford production sits at roughly 1.1 to 1.2 million barrels of oil per day across the formation, making it one of the top three most productive shale plays in the United States behind the Permian Basin and Bakken. The operators still working the formation actively have gotten much better at what they do — longer horizontal wells, more precise hydraulic fracturing (a process where pressurized fluid cracks the rock to release oil and gas), and tighter spacing between wells have all improved economics dramatically since the early years.
The major operators in the Eagle Ford right now include:
- EOG Resources, which pioneered much of the Eagle Ford development and remains one of the largest and most active drillers, particularly in Karnes and DeWitt counties
- ConocoPhillips, which significantly expanded its Eagle Ford position after acquiring Shell's assets in 2021 for roughly $9.5 billion — a signal that major companies still see long-term value here
- Marathon Oil (now absorbed into ConocoPhillips after their 2024 merger), which was heavily concentrated in the Karnes Trough area
- Devon Energy, active across multiple Eagle Ford counties
- Chesapeake Energy (now SWN/Expand Energy), which has a large dry gas position in Webb County near Laredo
The fact that companies like ConocoPhillips are still committing billions of dollars to this formation tells you something real about its longevity. These aren't speculative bets — they're capital allocation decisions made by companies with access to the best geological data available. Mineral owners can take some confidence from that.
For you as a mineral owner, understanding who's operating near your acreage matters for one practical reason: active operators mean active royalty checks. If you own rights in an area with a current lease and an active well, you're likely already receiving royalty payments — a percentage of the revenue from oil and gas sold from your land, typically ranging from 20% to 25% in modern Eagle Ford leases. If your land is leased but not yet drilled, or if your lease expired, your situation and your options are different.
What Your Mineral Rights Might Be Worth Right Now
Valuing mineral rights is not a simple formula, but it's also not a complete mystery. The main factors that determine value are: whether you have producing wells, your royalty rate, which Eagle Ford window you're in, your net mineral acres (NMAs), and current commodity prices.
Net mineral acres (NMAs) is the standard unit of measurement for mineral ownership. If your family owns a 25% mineral interest in a 160-acre tract, you own 40 NMAs. That's the number buyers will use to calculate an offer.
For producing mineral rights in the Eagle Ford oil window — particularly in the Karnes Trough area covering Karnes and DeWitt counties — values in recent transactions have ranged from roughly $15,000 to $40,000 per NMA depending on well performance, royalty rate, and operator quality. Exceptional acreage with high-producing wells and a major operator can go higher. Karnes County properties with EOG or ConocoPhillips leases and strong well data have traded at the top end of that range.
For non-producing or unleased mineral rights in the oil window, values vary more widely — typically $2,000 to $8,000 per NMA — depending on how close you are to active drilling and whether your acreage is likely to be leased in the near future.
In the dry gas window near Laredo and Webb County, values are considerably lower given suppressed natural gas prices. Dry gas mineral rights have been trading in ranges closer to $1,000 to $3,000 per NMA in recent years, though a sustained increase in LNG (liquefied natural gas) export demand could change that picture.
These are real market ranges, not guarantees for your specific situation. What they tell you is that the spread between the best and worst Eagle Ford acres is enormous — which is exactly why it's worth understanding your specific location before you make any decisions.
One more thing on this: royalty rates matter significantly to buyers. A 1/5 (20%) royalty on a producing well generates 25% less revenue than a 1/4 (25%) royalty on the same well. Buyers will discount offers accordingly. If you don't know your royalty rate, it's on your lease document — find it before you have any serious conversations about value.
Texas Taxes and What They Mean for a Sale
Texas has no state income tax, which is genuinely good news for mineral owners. But federal taxes still apply, and understanding them helps you make a smarter decision about timing and structure.
When you sell mineral rights, the IRS typically treats the proceeds as a capital gain — the profit you make above your cost basis (what you originally paid, or the stepped-up value at the time of inheritance). If you inherited your mineral rights, you almost certainly received a stepped-up cost basis equal to the fair market value at the date of the original owner's death. For many inherited mineral rights, this means the taxable gain on a sale is considerably smaller than the full sale price.
If you've owned the rights for more than one year (which is essentially everyone who inherited them), the long-term capital gains rate applies — currently 0%, 15%, or 20% depending on your income. Most mineral rights sellers fall into the 15% bracket. Add the 3.8% Net Investment Income Tax that applies to higher-income taxpayers, and the maximum federal rate is 23.8% on long-term gains.
Compare that to royalty income, which is taxed as ordinary income — meaning at your regular tax rate, which could be 22%, 24%, or 32% for many people. This is one reason some mineral owners, particularly those already in higher income brackets, find a lump-sum sale tax-efficient compared to continuing to receive royalty checks year after year.
Speak with a CPA before you finalize any decision. This is not optional advice — mineral rights transactions can involve significant dollars, and a one-hour consultation with a tax professional can save you real money. Texas has many CPAs who specialize in oil and gas taxation and are familiar with Eagle Ford transactions specifically.
The Market Outlook: What's Driving Activity in Eagle Ford Right Now
Several forces are shaping the Eagle Ford market in 2024 and looking forward into 2025 and beyond.
Oil prices are the dominant variable. West Texas Intermediate (WTI) crude — the benchmark price for most Eagle Ford oil — has traded in a range of roughly $70 to $85 per barrel for much of 2024. At those levels, the oil window of the Eagle Ford is highly economic for operators. If WTI were to fall below $55 to $60 per barrel and stay there, drilling activity would slow and mineral values would follow. Most major operators have reduced their breakeven costs significantly since 2015, so there's more cushion than there used to be, but oil price risk is real and you should factor it in.
Consolidation among operators is a meaningful trend. ConocoPhillips absorbing Marathon Oil is one example. When large companies acquire smaller ones, they sometimes rationalize their acreage portfolios — selling positions that don't fit their core strategy. This can reduce drilling activity in some areas temporarily. On the other hand, well-capitalized major operators tend to drill more consistently over time than smaller independents.
Natural gas and LNG are increasingly relevant for Eagle Ford owners in the condensate and dry gas windows. The United States has become the world's largest LNG exporter, and Texas Gulf Coast export terminals — within pipeline reach of the Eagle Ford — are a major driver of that growth. Several new LNG export facilities are under construction or in permitting. If natural gas prices recover from their current lows (around $2.00 to $2.50 per MMBtu as of mid-2024), condensate and dry gas window minerals could see meaningful value increases.
The mineral rights acquisition market itself remains active. Mineral buyers — companies that purchase mineral rights as an investment — are still actively acquiring Eagle Ford acreage, which means you have real options if you want to sell. Competition among buyers is healthy for sellers. In the Karnes Trough specifically, some of the most competitive bidding in the country takes place because the wells are simply that good.
The honest outlook: the Eagle Ford is a mature, well-understood play with decades of remaining production potential in the oil window. It's not a growth story the way the Permian Basin is, but it's a reliable, economically sound formation that will continue to be actively developed. That's a reasonable foundation for valuing your rights today.
Making a Smart Decision: How to Think About Selling vs. Holding
There's no universal right answer here. Some mineral owners should sell. Others are better off holding. The honest answer depends on a few things that only you can weigh.
Reasons to seriously consider selling:
- You need the capital now, or an estate is being settled and simplicity has real value
- You own rights in an area with limited near-term drilling activity, and the royalties are small or inconsistent
- You're in a higher income tax bracket and the tax efficiency of a long-term capital gain is meaningful to you
- You want to eliminate the uncertainty of commodity price swings from your financial picture
- You own a fractional interest with multiple heirs and managing it is creating family friction
Reasons to hold:
- You're already receiving strong, consistent royalty income and you have no pressing need for a lump sum
- You're in the core Karnes Trough area with a major operator actively drilling, and the wells are performing well
- You believe oil prices will increase substantially over the next five to ten years
- You want to pass the asset to your children, and the stepped-up cost basis at your death would minimize their tax burden
One specific scenario worth flagging: if you own mineral rights that are currently unleased, you should not be passive. An unleased mineral owner gets no royalties and has no control over when or whether development happens. Getting your acreage leased — ideally to an active operator in your area — puts you in a far better position, whether you ultimately decide to hold or sell. A mineral rights attorney in Texas (San Antonio and Austin both have firms that specialize in this) can help you understand your leasing options.
If you do decide to get offers, get at least three of them. The spread between the lowest and highest offer you receive can be surprisingly large — 20% to 40% is not unusual — simply because different buyers have different strategies and different assumptions about future drilling. This is not a situation where one phone call is enough research.
If you'd like to find out what your Eagle Ford mineral rights are worth, reach out through this site. A real person — not an automated system — will call you back, usually within one business day. That first conversation is a no-commitment exchange of information: you'll describe your acreage, and we'll tell you honestly what market activity looks like in your area and whether it makes sense to go further. If we make an offer, you'll have it in writing and you can take as much time as you need to review it, compare it, and discuss it with your family or attorney. No pressure, no deadlines.