If you own mineral rights in Texas, Louisiana, Colorado, Utah, North Dakota—or really any active oil and gas state—you’ve probably heard some big numbers lately.
And I mean big.
I’ve personally seen offers come in at $30,000+ per net mineral acre in certain areas.
So naturally, the first question most people ask is:
“What are mine worth?”
Fair question.
But here’s where people get tripped up:
Not all mineral rights are valued the same. Not even close.
In fact, minerals sitting right next to each other can vary by thousands of dollars per acre.
Same county. Same section. Sometimes even same family.
So if your neighbor got a strong offer, that does not automatically mean you will.
That’s just not how this works.
And that’s exactly why I put this guide together.
Quick Answer Box
How Much Are Mineral Rights Worth?
👉 $1,500 to $30,000+ per net mineral acre
It depends on:
- Location and geology
- Production status
- Operator activity
- Lease terms
- Development plans
Biggest mistake I see:
Assuming your minerals are worth what someone else got—even if they’re right down the road.
When it comes to mineral buy price, the most important information I give is this:
Offers to buy your minerals are presented in either Net Mineral Acres or Net Royalty Acres. Keep this in mind while considering the mineral values in this article. It can make a HUGE difference!
If you don’t know about this, stop now and read: Selling Your Minerals: One Detail Can Save You Thousands
What Actually Determines Mineral Rights Value?
Mineral rights aren’t priced randomly.
There’s always a reason behind the number—you just don’t always see it unless you know what to look for.
Here’s how I break it down for mineral owners.
1. Where Your Minerals Sit (Geology Matters More Than You Think)
Everyone says “location matters.”
That’s true—but not in the way most people think.
It’s not just where your land is…
👉 It’s what’s underneath it.
Formations like:
- Permian Basin
- Haynesville Shale
- Eagle Ford
consistently bring stronger offers because:
- They’ve already proven they can produce
- There are multiple productive zones in some areas
- Operators understand the geology
- Infrastructure (or “take away capacities”), is already in place
That’s why core Permian acreage might bring $25K–$35K+, while something in a less developed Chalk area might be $1,500–$8,000.
Same state. Completely different value.
Reality Check:
Mineral rights sitting right next to each other can have wildly different values. I’ve seen that happen over and over again, and it’s one of the biggest reasons mineral owners get confused when they start comparing offers.
2. Are Your Minerals Actually Doing Anything?
This one’s simple—but a lot of people overlook it.
Buyers look at your minerals like this:
- Producing, with brand new development coming → highest value
- Newly Producing → still has high value
- Producing → good, consistent, predictable value (but depends)
- Leased (not producing yet) → still strong
- Unleased near activity → depends
- Unleased with no activity → low to minimal value
Why?
Because producing minerals are already making money, more easily put, ROI.
That’s an immediate return—and buyers will pay for that.
Leased minerals can still carry strong value if the operator is active and development looks likely.
Unleased minerals can still be valuable too—but there’s usually more uncertainty involved.
Here’s how it breaks down:
| Status | Typical Offer Range |
|---|---|
| Producing, High Royalty | $15,000 – $35,000+ / acre |
| Leased but Non-Producing | $7,500 – $20,000+ / acre |
| Unleased, Near Active Area | <$5,000 – $12,000 / acre |
| Unleased, Low Activity | <$1,500 – $5,000 / acre |
Producing minerals generate monthly royalty checks and offer immediate returns for buyers. That’s why they command top dollar.
Leased minerals—even if not yet producing—are valuable if the lease is held by a reputable operator in an active area.
Unleased minerals without clear near-term drilling plans typically receive lower offers, but strategic positioning near hot spots can still drive demand.
3. Who’s Active Around You (This Can Change Everything)
This is where things can shift fast.
If your minerals are near active operators—whether that’s Diamondback, ExxonMobil, EOG, or other top tier operators—you’re in a completely different position than someone in a quiet area.
Buyers are watching:
- Rig counts
- Permit filings
- Acreage acquisitions
- Expansion plans
- M&A activity
And when things start heating up?
👉 Values can jump quickly.
I’ve seen areas move 20–40% in a matter of weeks to months when activity picks up.
And I’ve also seen the opposite—where operators pull back and values drop just as fast.
4. Lease Terms (This Is Where People Quietly Lose Money)
This one doesn’t get talked about enough.
Two owners can have the same production—and completely different values.
Why?
Because of lease terms.
Things like:
- Royalty rate (12.5% vs 20–25% is a big deal)
- Cost-Free Royalty with no post-production deductions
- Favorable pooling provisions
- Horizontal and Vertical Pugh Clause
Example:
Someone with a 25% cost-free royalty will almost always get a stronger offer than one with an older 12.5% lease with all sorts of pre and post production costs taken out—even if both are producing the same volume. Reason being–more royalty acres and less deductions equal higher revenues.
Same wells. Different outcome.
Mineral Rights Value by Region (What I’m Seeing Right Now)
Let’s talk real-world ranges.
These are not guarantees—but they’ll give you a realistic ballpark.
Regional Value Snapshot
| Region | Typical Range |
|---|---|
| Permian Basin | $10,000 – $30,000+ |
| Eagle Ford | $5,000 – $15,000+ |
| Austin Chalk | $1,500 – $8,000+ |
| Haynesville Shale | $4,500 – $15,000+ |
| Bakken | $3,000 – $12,000+ |
| DJ & Niobrara | $2,500 – $10,000+ |
| Uinta Basin | $2,000 – $20,000+ |
Permian Basin (West Texas and South Eastern New Mexico)
Core counties still command premium pricing because of stacked zones, long-term drilling inventory, and heavy operator competition.
Counties Showing High Operator Activity (Based on New Horizontal Permits): Texas: Loving, Reeves, Ward, Winkler, Midland, Martin, Glasscock, Howard, Upton, Reagan and New Mexico: Lea, Eddy
Why These Areas Are Special:
- Active Wolfcamp, Bone Spring, and Spraberry development
- Multiple stacked pay zones (multi-decade drilling inventory)
- Strong operator competition (Diamondback, ExxonMobil, EOG, Occidental, etc.)
- Defined development timelines with infill drilling programs
- Established takeaway and export infrastructure
These counties continue to show consistent new horizontal permit filings and multi-well pad development programs.
According to our Permian Basin valuation research, mineral buyers are paying premium prices in core counties where development timelines are defined and long-term drilling inventory remains strong.
Eagle Ford (South Texas)
Strong oil corridors still matter here, especially where infill drilling and optimization continue.
Counties Showing High Operator Activity (New Permits & Development): Karnes, DeWitt, Gonzales, Lavaca, Live Oak, McMullen, La Salle, Dimmit, Webb
Why These Areas Are Special:
- Strong oil production corridors in Karnes and DeWitt
- Ongoing infill drilling and re-frac activity
- Excellent access to Gulf Coast refineries and export terminals
- High royalty rates in many legacy leases (20–25%)
Permit activity remains steady in core oil window counties, especially where operators are optimizing spacing.
In my Eagle Ford market breakdown, pricing varies significantly by county and development stage, with buyers concentrating on the most productive corridors.
Austin Chalk (South and East Texas)
More speculative in some areas, but select counties are seeing renewed attention.
Counties Showing Increased Activity: Brazos, Burleson, Robertson, Washington, Lee
Why These Areas Are Special:
- Renewed interest in the Austin Chalk extension
- Horizontal redevelopment targeting legacy vertical zones
- Adjacent Eagle Ford activity influencing leasing momentum
- Speculative upside tied to emerging drilling corridors
New permits in these counties reflect testing of extended Austin Chalk fairways.
Dig deeper with our Austin Chalk valuation guide to learn how renewed leasing, reworked wells, and nearby Eagle Ford activity are influencing buyer interest despite lower average pricing.
Haynesville Shale (East Texas, Northwest Louisiana)
This one is heavily influenced by gas markets, LNG demand, and development timing.
Counties / Parishes with High Permit Activity: Texas: Panola, Harrison, San Augustine, Leon, Robertson, Freestone and Louisiana: DeSoto, Caddo, Bossier, Sabine, Red River
Why These Areas Are Special:
- High-flowing dry gas wells
- LNG export-driven demand growth
- Western Haynesville extension or “Waynesville”, gaining attention
- Longer laterals and improved frac designs increasing recoveries
My original Haynesville Shale analysis highlights how operator timelines, gas marketing contracts, and LNG exposure impact mineral values.
Bakken (Montana, North Dakota)
A mature basin, yes—but still very relevant in strong core areas.
Counties with High Operator Activity: McKenzie, Mountrail, Dunn, Williams (ND), Richland (MT)
Why These Areas Are Special:
- Mature but efficient oil play
- Re-frac programs extending PDP life
- Consolidated operator footprint
- Strong oil pricing relative to basin economics
DJ & Niobrara (South Dakota, Colorado, Nebraska, Wyoming)
Counties with Strong Activity: Weld County, Adams, Morgan (CO) and Laramie County (WY)
Why These Areas Are Special:
- Niobrara horizontal development
- Improved economics from longer laterals
- Consistent operator presence
Permit filings in Weld County remain dominant in the basin.
Uinta Basin (Pennsylvania, West Virginia, Ohio, New York)
Smaller market, but not one to ignore. Certain areas continue to attract serious interest.
Counties with Active Development: Uintah County, Duchesne County
Why These Areas Are Special:
- Waxy crude premium markets
- Private operator-led development programs
- Improved takeaway infrastructure
- Emerging horizontal redevelopment strategies
When Should You Sell? (This Is Where People Get It Wrong)
This is where I’ve seen people do really well…
…and where I’ve seen people miss it completely.
1. When Activity Is Picking Up (But Not Finished)
The sweet spot is usually:
👉 When operators are moving in—but development isn’t fully built out yet.
Watch for:
- New permits
- Rigs showing up
- Lease offers increasing
- Buyers calling out of nowhere
That’s usually not random.
2. When Buyers Start Showing Up at the Same Time
If multiple buyers are reaching out, that’s not coincidence.
That’s competition.
And competition is what pushes values up.
3. The Risk Nobody Talks About (Waiting Too Long)
While waiting might feel like a way to “hold out for more,” there are real risks to holding mineral rights too long:
- Decline curves: Wells naturally lose production over time, reducing royalty income—and the resale value of your minerals.
- Operator pull-outs: Companies shift capital constantly. If they leave your area, your minerals may become dormant and unsellable for years.
- Regulatory or tax changes: Future laws could impact valuation or impose capital gains burdens.
💬 Example: An owner in the western Eagle Ford region, while under a lease with the clock ticking and drilling taking place in and around the area, declined multiple high six and low seven figure offers in 2021 and 2022 while hoping and waiting for drilling. By 2024, the productive drilling area got more defined and the operator exited the area and their lease expired—and by 2026, offers had fallen by over 60%.
What happened?
Over time it was learned the wells in the area were not as productive due to major geologic faults in the immediate area. Fast forward to today, this acreage is still unleased with nothing new on the horizon.
Timing Warning:
Waiting can cost you! I’ve seen owners pass on strong offers, only to watch operators leave, leases expire, or values drop once the area lost momentum. Sometimes waiting pays off. Sometimes it doesn’t. That’s why timing matters more than most people think, almost as much as what is under the ground.
Takeaway:
The best time to sell mineral rights is often when activity is visible but not yet saturated—when operators are moving in, but competition for acreage is still hot. It’s also when experienced mineral buyers are willing to compete for deals and offer favorable terms.
If you’re unsure and lack the specific tools and knowledge, working with a firm that monitors both buyer activity and local drilling trends—like Venergy Momentum—can help you make data-backed decisions, not emotional ones.
While many landowners grew up hearing ‘never sell your minerals,’ today’s market realities—ranging from global and geopolitical price swings to shifting buyer interest—make partial, and even complete sales a smart, strategic move for many.
Want to know what it takes to sell mineral rights? Get a look at how it’s done in our article, Preparing to Sell Your Minerals and Royalties, It’s More Than What You Think.
Common Questions Mineral Owners Ask
What’s the Best Way to Estimate My Mineral Rights Value?
There’s no “one-size-fits-all” calculator for mineral rights—because values change based on location, geology, lease terms, production status, operator demand, etc. If you start by following the advice below you will be in a great starting place. Understanding your interests with expert help will give you the knowledge and confidence you need to make smart decisions and prevent getting taken advantage of.
Tip 1: Don’t Do It Alone–Get Expert Help
At Venergy Momentum, we offer mineral rights evaluations based on real market data, recent transactions, and technical subsurface mapping. This isn’t a computer-generated guess—it’s an expert-led process tailored to your specific acreage and surrounding activity.
Tip 2: Review Offers, But Don’t Accept the First One
If you’ve received unsolicited offers, that’s a good sign your minerals are valuable. But don’t assume those offers reflect your land’s full market potential, in most cases they most certainly DO NOT. Some buyers start low, expecting negotiation—or that you won’t know your leverage.
Unfortunately, unsuspecting mineral owners often take the bait in their first offer because they just don’t know any better, and the offer being presented is more money than they’ve seen at one time, so they accept without thinking twice.
Don’t let this happen to you! We can help get you the offers you deserve.
Read Now: Why Mineral Owners Fall for (Seemingly) High Offers from Mineral Buyers
Tip 3: Research Public Drilling and Production Activity
Look up new well permits and operator activity in your county through sites like the Texas Railroad Commission (TX) or SONRIS (LA). Every oil and gas producing state will have its own similar site. We do our best to keep a page updated with Quick Links: State by State Oil and Gas GIS Mapping Applications for Public Use. If your land is near high-output wells or active rigs, that boosts your negotiating power!
Who’s Most Likely to Get Undervalued?
This is important:
Who’s Most at Risk of Underselling?
- Heirs who didn’t know they inherited mineral rights
- Out-of-state owners disconnected from activity
- Small-check recipients who undervalue what they own
- Elderly owners offered seemingly big numbers — but well below market
- Uninformed sellers unsure of what they actually hold
In other words:
👉 People who don’t realize what they have.
Should I Sell If My Minerals Aren’t Producing?
Yes—non-producing mineral rights still hold value, especially if they’re in the path of drilling activity, already leased, or even unleashed in some cases (mineral buyers love to negotiate their own lease terms).
Here’s how it breaks down:
When Selling Makes Sense:
- Your acreage is in an active or emerging shale play (e.g., Permian, Haynesville, Eagle Ford, or Uinta)
- An operator recently leased your minerals or a neighbor’s tract
- You’d prefer a lump sum now vs. waiting years for uncertain royalties
Case Example:
A mineral owner in Burleson County, TX, who never signed an oil and gas lease nor ever received any royalties sold non-producing Austin Chalk rights in Q1 2026 for $5,000/acre—thanks to new leasing momentum in the area. The seller thought the buyer was crazy, but the buyer was betting on signing a new oil and gas lease with favorable terms and hoping for horizontal development within the next 18 months. Not to mention, the seller had fewer taxes owed on the lump sum payment due to how long they owned the minerals for (longer than one year).
When Holding Might Work (but, this is a very personal decision!):
- You have just a few, or possible, multiple old vertical legacy producing wells or pending permits
- You’re comfortable waiting several years for royalties that may or may not arrive
- You’ve received legal or tax advice that favors holding (e.g., for estate planning)
Tip: Selling non-producing minerals can be a strategic move—especially if development timelines are unclear or you need immediate liquidity.
Many owners don’t realize their interests may be worth more than what buyers offer — especially if they inherited mineral rights. In fact, they may have never even known they owned minerals and royalties prior to someone contacting them.
We provided clear, fact based consultations, engineering-backed Retrospective Appraisals that calculate your mineral value at the time of inheritance, and much more. All of which can drastically benefit your decision making process, and potentially reduce your tax burden and reveal true market worth.
How to Get a Fair Offer: What to Look For in a Buyer
The mineral rights market is more competitive than ever. Dozens of buyers may reach out—but not all offers are created equal. A fair offer isn’t just about price. It’s about trust, transparency, and who you’re doing business with.
Here’s how to evaluate a buyer before signing anything.
Trust, Transparency, and Track Record Matter
A credible mineral buyer should:
- Clearly explain what they think you own and how they value your minerals (not just throw out a number)
- Provide clean, well-written contracts with no confusing fine print
- Be willing to answer your questions TRUTHFULLY—not rush you into signing
- Offer verifiable references, testimonials, or deal history
- Be easy to reach and responsive throughout the process
Red Flags to Watch For:
- “This deal expires tomorrow”
- Vague contracts
- No explanation behind the number
- Pressure to sign quickly
If something feels off…
👉 It usually is.
At Venergy Momentum, we focus on educating landowners first and walking them through the process of how to sell mineral rights, even if it means they decide not to sell. Our goal is to empower you with enough knowledge to make the right decision based on your specific, personal situation, and on your timeline.
“We’re not the kind of company that receives and sends you one offer amount and hopes you bite. We walk mineral owners through the details: comps, formations, development situations, and offer context—because a fair deal starts with clarity.”
– Kyle D. Venema, Owner
How to Tell If a Buyer Is Legit (or Not)
Not all buyers operate the same way.
Not even close.
Good Buyers Will:
- Explain how they got their number
- Answer your questions clearly
- Give you time to think
- Be transparent about the process
Watch: Should I Sell My Minerals?
Watch this before you make any decisions:
What Happens After I Sell?
Selling mineral rights doesn’t mean you lose or even have to sell your land if you own the surface. It simply means someone else will own the subsurface interest going forward. You will be selling whatever net mineral acres (NMA) you own—the portion of total subsurface rights you own rights to. Here’s what to expect after the deal:
The Process:
- Offer & Agreement — You receive a written offer and you have a professional that knows what they’re doing to help you negotiate the offer.
- Execution of PSA — You sign a purchase and sale agreement (PSA).
- Title Review — The buyer verifies ownership via public records and deeds.
- Closing — Once cleared, you receive a lump sum payment via check or wire.
- Transfer — The deed is filed with the county–the buyer now owns the mineral interest and will start the transfer of ownership with the operator/payor if the interest is producing.
Payments & Tax Considerations:
- You may receive a 1099 form if the sale amount exceeds reporting thresholds. It depends on the buyer and how they’re company is structured.
- Capital gains OR ordinary income taxes may apply, depending on how long you’ve owned the mineral and/or royalty rights.
- Consult a CPA or mineral rights tax specialist to plan accordingly.
- Determine whether or not a Retrospective Mineral and/or Royalty Appraisal is necessary.
How Buyers Use the Rights:
- Lease the minerals to oil and gas operators
- Collect royalties from producing wells
- Hold the rights as speculative investments
Did you know? Mineral buyers aren’t always drilling companies—many are mineral funds or private equity groups building portfolios of rights across active basins.
Frequently Asked Questions About Mineral Rights Value
How do I calculate mineral rights value?
There’s no fixed formula. Value depends on location, production, lease terms, and activity nearby.
Are producing minerals worth more?
Yes. They generate income, which makes them more valuable to buyers.
Can I sell part of my minerals?
Yes. Many owners sell a portion and keep the rest.
Should I accept the first offer?
Usually not. First offers are often low.
Not Sure What Yours Are Worth?
If you’ve made it this far, you probably already realize something:
👉 There’s a lot more to this than most people think.
And without looking at your exact situation—location, activity, lease details—any number you’ve been given is just a guess.
That’s what I help mineral owners figure out every day.
- What you actually own
- What’s happening around you
- What buyers are really looking at
- And whether selling even makes sense right now
No pressure. No obligation.
Just a real conversation.
Why Work With Venergy Momentum?
When it comes to selling mineral rights, experience matters—but so does transparency. At Venergy Momentum, we combine data-driven Retrospective appraisals, industry experience, helping landowners make confident decisions—not rushed ones.
What sets us apart:
- Real Testimonials from landowners who’ve successfully sold rights in the Permian, Haynesville, Eagle Ford and Austin Chalk, DJ Basin, Uinta Basin, and many more
- Visual summaries of recent deals, offers, and production activity by county or parish
- Easy access to our Services Page, Client Reviews, and Contact Form
We don’t buy mineral rights—we educate landowners across every state including Texas, New Mexico, Colorado, Utah, North Dakota, Louisiana, and many more so they can negotiate from a position of strength.
No pressure. No commitment. Just answers.
Landowners in Texas, New Mexico, Colorado, Utah, North Dakota, and Louisiana have real options when it comes to selling mineral rights—but timing, trends, and shale activity shift quickly.
Before you accept an offer (or wait too long), talk to me. Let’s talk about your specific situation, where your minerals are located, the activity in your area, and your market leverage.
Contact Venergy Momentum to get started with your mineral rights evaluation today.
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