The Complete Guide to Mineral Rights 1031 Exchanges.

The IRS position that oil and gas royalty interests are real property is sixty years old and consistent. It is not a loophole or a gray area — it is the same legal treatment used by farmland owners, rental-house investors, and commercial landlords every day. The foundational ruling is Rev. Rul. 68-331 (1968), which established that real estate ownership interests, whether above or below the ground, meet the “like-kind” definition for an exchange.

What “real property” means here.

The technical answer: an interest in the right to extract oil and gas from a specific tract of land is treated, for 1031 purposes, the same as ownership of that land. The plain-English answer: owning a Permian royalty is legally analogous to owning a piece of Permian dirt. You can exchange one for another, or for any other qualifying real property, under the same rules a real-estate investor uses to roll between rental houses.

The authority stack.

Beyond Rev. Rul. 68-331, four decades of court rulings and additional Revenue Rulings have re-affirmed that oil and gas royalty interests qualify as like-kind to all other forms of real property — including Rev. Rul. 55-526, Rev. Rul. 73-428, PLR 8135048, Crichton v. Commissioner (122 F.2d 181), and Palmer v. Bender (287 U.S. 551). The result: an oil and gas royalty owner sits inside the same 1031 framework a commercial-real-estate owner uses every day.

The three identification rules.

By day 45 you have to deliver a signed, written list of replacement candidates to the QI. Three rules govern that list:

Three-property rule. Identify up to three properties of any value. This is the default playbook for most exchanges.
200% rule. Identify more than three, as long as their combined fair-market value is no more than 200% of the relinquished interest.
95% rule. Identify any number of properties of any value, but you must actually close on 95% of the identified value. Rarely used — the math is unforgiving.

A realistic timeline.

Day -15. Share your exchange details. Review a candidate royalty portfolio. Show your CPA.
Day -5. Sign the purchase agreement.
Day 0. Proceeds wire to the QI. Clock starts.
Day 30. Touring replacement properties or vetting DST offerings.
Day 45. Signed identification list to the QI before midnight.
Day 60–150. Diligence on the chosen property — title, environmental, lender approval, tenant credit review.
Day 180. Replacement closing. Deferral complete.

Why owners actually miss the clock.

Starting valuation late. Lining up the right royalty portfolio takes time. CPA review adds another five. Purchase-agreement signing takes two or three. If the seller hasn't started by day -15, the math gets tight.

Identifying too narrowly. Sellers who list only one DST on their 45-day form have no fallback if the trust closes early, pulls funding mid-diligence, or fails to underwrite. Identifying two or three candidates is the standard playbook for a reason.

Underestimating closing diligence. A NNN property close involves title work, environmental review, tenant estoppels, and lender approval. Plan for three to four weeks of real work, not two.

How depletion works, and why recapture hurts.

Mineral owners typically claim one of two depletion methods against royalty income: percentage depletion (a statutory 15% for oil and gas, applied to gross income from the property) or cost depletion (based on the property's adjusted basis, depleted in proportion to units produced). Either way, the depletion you take reduces your basis in the interest.

When you sell, the IRS recaptures the depletion as ordinary income, not capital gain. That matters because ordinary-income rates run materially higher than long-term capital gains rates — up to 37% federal versus 20% for most sellers in the top bracket. Whether a 1031 exchange defers the recapture is fact-specific and depends on the interest type, the structure of the replacement property, and timing of the transaction. This is squarely a CPA-only question; do not rely on this page for the answer.

Inheritance changes the math.

Under IRC 1014, inherited interests receive a stepped-up basis at the decedent's date of death — fair market value, not original cost. An owner who inherited a Permian royalty worth $750,000 from a parent has a basis of $750,000, regardless of what the parent paid for the lease in 1978.

In practice, this means many inherited owners have little or no capital gains exposure on a sale. The exchange may still be the right path — for steady income, estate planning, or portfolio diversification — but it is not strictly necessary for tax deferral. Worth confirming with the estate's CPA before committing to the structure.

How sellers actually pair these.

Most exchanges don't go into a single property type. The common pairings:

Inherited royalty → DST + farmland. The DST handles the bulk of the proceeds quickly (identifiable on day 1) and the farmland gives the family something tangible they can drive to. Removes the timing pressure of identifying multiple NNN deals in 45 days.

Long-held producing royalty → NNN commercial. Predictable yield, defined cap rate, replaces operator decline-curve risk with tenant credit risk. Works for owners who want monthly income at a known number.

Concentrated basin position → other royalties. Owners who like the asset class but want to shift geography (Bakken → Permian, single-county → multi-basin) keep the 1031 cover while diversifying inside the same category.

Closing diligence by category.

NNN. Title, ALTA survey, environmental Phase I, tenant estoppels and SNDA, lender approval if financed. 3–4 weeks of real work.
DST. Sponsor due diligence (track record, sponsor capital, fee structure), trust documents, PPM review. 1–2 weeks if the sponsor is responsive.
Farmland. Title, water rights, mineral severance check, soil tests, existing lease review. 2–3 weeks.
Other minerals. Division-order review, title chain, well-by-well decline analysis, operator credit check. 2–3 weeks.

Related-party rules in plain English.

Under IRC 1031(f), exchanges between related parties (family members, controlled entities, partnerships and their partners) face a two-year holding period. If either party disposes of the property within two years, the original deferral collapses retroactively. Peregrine is never a related party to a seller, but if there are intermediate transfers in the structure — an LLC step, a trust assignment, a family partnership — they need scrutiny before the QI funds.

Boot, deliberately.

Boot is cash or non-like-kind property received as part of the exchange. It is taxable to the extent received — not the whole transaction, just the boot portion. Sellers sometimes take boot intentionally: $50,000 of cash to cover closing costs while exchanging the rest into real estate, or accepting installment-note paper instead of a clean swap. Be deliberate. Surprise boot from a math error at close is what wrecks deferrals.

Constructive receipt and why the QI is mandatory.

The seller cannot, at any point in the timeline, take possession of the sale proceeds. Funds flow directly from Peregrine to the registered Qualified Intermediary, and from the QI to the replacement property's closing agent. If the seller's bank account ever sees the money — even briefly, even by mistake — the deferral is gone. This is why a registered QI is structurally required, not just a convenience.

The exchange equation.

To fully defer the gain, two things must hold: the replacement property's value must be equal to or greater than the relinquished interest, and the seller must take on equal or greater debt. Buying smaller creates boot in the gap. Trading down on debt creates “debt boot,” which is also taxable.