Owners ask us to explain the number behind an offer more than any other question. Fair question. Here's the actual math, not the sales pitch version.
Twenty-five years running title and pricing tracts across half the plays in this state has taught us one thing: two interests that look identical on paper can be worth very different amounts once you factor in where they actually sit in a basin.
There's no single formula that spits out a number. There's a method, applied differently depending on whether the tract is producing, undeveloped, or somewhere in between.
Producing tracts: decline curve first
If there's an active well, the starting point is its production history: how much oil and gas it's made, how fast the rate has fallen off month to month, and where it sits on the decline curve now. Wells drilled with modern horizontal completions typically show a sharp early decline that flattens over time, so where the well currently sits on that curve matters more than its peak rate did.
From there we estimate remaining reserves and apply a discount rate to future cash flow, since a dollar of royalty five years from now is worth less than a dollar today. That's the discounted cash flow method, and it's the backbone of pricing any producing interest.
Undeveloped acreage: activity, not production
No well means no decline curve to lean on, so the pricing question becomes: how likely is a well to get drilled here, and how soon? That depends on permitting activity nearby, which operators are leasing and drilling in the immediate area, and where the tract sits relative to the productive core of the play versus its flank.
Acreage in the core of an active basin, where operators are consistently permitting and drilling, prices differently than acreage on the edge of the play where activity has slowed or never really arrived.
Discount rate: the piece owners overlook
The discount rate applied to future cash flow accounts for risk and the time value of money, and it can move a valuation as much as the reserve estimate itself. A higher discount rate reflects more uncertainty, a newer well with less production history, a basin with more commodity price sensitivity, or a smaller, less-established operator running the lease.
Ask what discount rate a buyer used, and why. It's a fair question, and the answer tells you a lot about how conservative or aggressive their overall number really is.
Comparable sales, used carefully
Recent sale prices for similar interests nearby offer a sanity check on a number, but comparables in oil and gas are trickier than in real estate. A sale two sections over can reflect a completely different formation depth, spacing, or operator plan than your tract.
We use comparables to confirm a range is reasonable, not to set the price outright. Anyone quoting you a number based only on what a neighbor got paid is skipping the actual analysis.
Why basin position moves the number more than county lines do
Two tracts in the same county can be worth very different amounts if one sits in the productive core of a play and the other sits on a quiet flank where operators haven't drilled in years. That's why we think in terms of basin and play position first, county second.
A Delaware Basin tract in Reeves or Loving County with active operator development nearby is a different conversation than a quiet Anadarko Basin tract in the Texas Panhandle where drilling has been slow. Both are real Texas mineral interests. They price differently because the basin behind them is behaving differently right now.
Texas Owner Questions
Why did you get different numbers from two different buyers?
Different buyers weigh decline curves, discount rates, and nearby activity differently. Ask each one to walk you through their math, then compare the reasoning behind each figure rather than the number alone.
Does an appraisal give you an exact market value?
It gives a well-reasoned range, not a guaranteed figure. Oil and gas value moves with commodity prices and drilling activity, so any honest number is tied to current conditions.
Is undeveloped acreage always worth less than producing minerals?
Usually per-acre, since there's no current cash flow to price against. But undeveloped acreage in a hot part of an active basin can still carry real value based on drilling likelihood.
What information should you have ready before getting priced?
Recent royalty statements if you're receiving them, your net mineral acres, the county and, if you know it, the basin or play your minerals sit in. That's usually enough to start.
Do buyers use software, or is this still manual work?
Both. Decline curve modeling and cash flow discounting run through software, but interpreting nearby permitting activity and basin context still takes a person who understands what that activity actually means on the ground.
Can commodity price swings change your valuation between offer and closing?
It's possible on a longer timeline, though most closings move quickly enough that this rarely becomes a real issue. A buyer should tell you directly if market movement is affecting the number.
