By Brad Caponigro · Founder, Pointer Petroleum LLC · Reservoir engineer
Published · Updated
For Attorneys & CPAs
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IRC § 613 grants percentage depletion for natural resources broadly. IRC § 613A, added by the Tax Reduction Act of 1975, repealed percentage depletion for oil and gas — except for the categories preserved in § 613A(c).
The two preserved categories that matter for an estate-and-tax practice serving mineral owners:
— The "independent producer" category under § 613A(c)(1): producers other than integrated oil companies, up to a daily depletable quantity of 1,000 barrels of oil or 6 million cubic feet of gas, on a combined depletable-quantity basis.
— The "royalty owner" category implicit in § 613A(d)(3) and (5): owners of economic interests who do not operate the wells and who receive royalty / overriding-royalty / NPRI income are within the small-producer class for purposes of § 613A.
Almost every individual mineral-royalty owner an attorney or CPA will encounter falls within § 613A(c). The deduction is 15% of gross income from the property under § 613A(c)(5) (the rate Congress fixed at 22% in 1975, stepped down to 15% by 1984). It is computed property-by-property, but reported in aggregate on Schedule E.
Two limits constrain the percentage-depletion deduction for any given year:
1. 100%-of-net-income-from-the-property cap (§ 613(a)). Percentage depletion on a single property cannot exceed the net income from that property. For an active producing royalty interest where the only direct expense is severance tax and a small allocation of state filing costs, the 100%-of-net cap rarely binds. It does bind in years when production is curtailed or when post-production-cost charges to a non-cost-free royalty interest leave net income near zero.
2. 65%-of-taxable-income cap (§ 613A(d)(1)). Percentage depletion deductions in the aggregate cannot exceed 65% of the taxpayer’s taxable income for the year, computed without the depletion deduction itself, the NOL deduction, certain capital-loss carrybacks, and certain trust distributions. For a retirement-age royalty owner whose taxable income is dominated by the royalty itself, the 65%-cap is the live constraint. Excess percentage depletion disallowed by the 65%-cap carries over to subsequent years under § 613A(d)(1) (last sentence) — it is not lost.
A worked example: a single owner’s 2025 federal taxable income before depletion is $200,000, of which $180,000 is gross royalty income. Tentative percentage depletion is 15% of $180,000 = $27,000. The 65%-cap on $200,000 is $130,000. The cap does not bind — the full $27,000 is allowed in 2025. In a year where the same owner sells producing acreage and recognizes a $4M long-term capital gain on top of $180,000 of royalty, taxable income is dominated by capital gain; the 65%-cap on a much larger taxable-income base is much higher than $27,000, and again the cap does not bind. The cap routinely binds for taxpayers whose only income is royalty and who operate at a thin margin.
For each property each year, the taxpayer computes both methods and takes the larger:
— Cost depletion: adjusted basis in the property × (units produced this year / total recoverable units estimated as of the start of the year). Recoverable units are estimated by an engineer’s reserve report at acquisition or by reasonable extrapolation from production history.
— Percentage depletion: 15% of gross income from the property, subject to the two limits above.
For inherited royalty interests with stepped-up basis from a recent date of death, cost depletion can briefly exceed percentage depletion in the first year or two — the basis is high relative to remaining recoverable production. After basis is largely recovered, percentage depletion almost always wins.
For purchased mineral interests with low or zero basis, percentage depletion almost always wins from year one.
The practical workflow: maintain the depletion calculation per property each year and document which method was selected. Many CPAs default to percentage depletion without running the cost-depletion comparison; that is usually the right answer but is not always.
Whichever depletion method is taken, basis is reduced under § 1016(a)(2) by the depletion claimed. Cost depletion cannot reduce basis below zero by definition. Percentage depletion, however, has a special floor:
§ 613A(c)(7)(B): once basis reaches zero, percentage depletion may continue to be claimed against gross income from the property — it does not stop because basis is exhausted. This is one of the few preferential carve-outs in the Code where a deduction continues after basis recovery is complete.
The consequence: for long-held inherited interests, owners may be claiming percentage depletion for decades against a zero-basis interest. The deduction continues; basis just does not go further negative. This is not a tax shelter — the deduction is recaptured on sale (next section) — but it is permanently allowed against ordinary royalty income year by year.
When a mineral property is sold, IRC § 1254 recaptures the depletion previously claimed:
— The amount recaptured as ordinary income is the lesser of (a) the gain realized on the sale, or (b) the cumulative depletion deductions previously allowed (cost or percentage), plus any IDC deductions if a working interest.
— Gain in excess of recapture is long-term capital gain (assuming the holding period is satisfied).
For an inherited royalty interest where the owner has claimed 15 years of percentage depletion against, say, $90,000 of cumulative gross royalty (15 × $6,000/yr) and has cumulatively deducted $13,500, a sale at a $200,000 gain over remaining basis would recapture the $13,500 as ordinary income, with the balance ($186,500) as long-term capital gain. This is the workflow CPAs run on every sale of a long-held producing royalty.
Basis tracking matters here. An owner who never tracked depletion deductions taken cannot reliably compute § 1254 recapture on sale. CPAs preparing returns for royalty-owner clients should keep a depletion log per property in the working papers — not to defend the current return’s deduction, but to defend the eventual sale.
Percentage depletion in excess of basis is an AMT preference item under IRC § 57(a)(1) for taxpayers other than the small-producer / royalty-owner class. The royalty-owner exemption from § 57(a)(1) was added by the Tax Reform Act of 1986 and is preserved today: percentage depletion claimed by independent producers and royalty owners under § 613A(c) is not a tax-preference item.
In practice, individual royalty owners deducting percentage depletion against royalty income on Schedule E do not owe AMT on the deduction. Practitioners running the Form 6251 calculation for these clients should not add back the depletion preference. The exception bites only for integrated oil companies and a narrow set of large-producer cases that do not arise in the practice domains served by this resource hub.
Five percentage-depletion mistakes recur on royalty-owner returns:
1. Failing to claim it at all. Generalist preparers treating royalty income like interest — reporting gross with no depletion offset — overstates the tax liability. The 15% deduction is one of the highest-leverage adjustments on a Schedule E return.
2. Computing depletion on the wrong base. The deduction is 15% of gross income from the property, not 15% of net (after post-production deductions in non-cost-free leases). Using net for percentage depletion understates the deduction.
3. Skipping the cost-depletion comparison in early years of an inherited interest. For interests with substantial stepped-up basis and modest current production, cost depletion can produce a larger deduction in the first year or two.
4. Failing to maintain a per-property depletion log. The cumulative figure governs § 1254 recapture on the eventual sale. CPAs who reconstruct the log from years of returns at the time of sale produce a weaker audit posture than CPAs who maintained it contemporaneously.
5. Misapplying the 65%-of-taxable-income cap. The cap operates on aggregate percentage depletion, not on each property separately, and the carryover provision means the cap is not a permanent loss — disallowed amounts roll into subsequent years. Treating capped amounts as expired wastes future deductions.
It applies to all economic interests in oil and gas property held by a non-integrated, non-large-producer taxpayer. Royalty interests (RI), non-participating royalty interests (NPRI), and overriding royalty interests (ORRI) all qualify when held by an individual royalty owner or small estate. Working interests held by independent producers also qualify but are subject to the 1,000-bbl / 6-MMcf daily depletable-quantity limit.
Under § 613A(c)(7)(B), percentage depletion continues to be allowed even after basis is fully recovered — basis floors at zero and does not go further negative. The deductions continue to flow against gross royalty income year by year. On any future sale, § 1254 will recapture the cumulative depletion claimed (limited to the gain realized) as ordinary income, with the balance as long-term capital gain.
The cap binds for taxpayers whose taxable income is dominated by royalty income with thin margins or who have unusually low taxable income in a given year (e.g., from large unrelated losses). The disallowed amount is not lost — it carries over to subsequent years under § 613A(d)(1) (last sentence). Practitioners encountering a cap year should compute the carryover amount and flag it on the workpapers for the following year’s return.
No. The § 57(a)(1) AMT preference for percentage depletion in excess of basis specifically excludes the small-producer / royalty-owner class under § 613A(c). Form 6251 should not include a depletion preference add-back for these taxpayers. The preference is alive only for integrated oil companies and a narrow set of large-producer cases.
Recapture under § 1254 is the lesser of (a) the gain realized on the sale, or (b) the cumulative depletion deductions allowed over the holding period. Recaptured amount is ordinary income; gain in excess of recapture is long-term capital gain. The cumulative-depletion figure should be drawn from a per-property depletion log maintained on the workpapers; reconstruction from filed returns is weaker but acceptable if the log was not kept.
Primary sources used in writing this article. These are not legal or tax advice — they are the public statutes, regulations, and authoritative materials the article draws from. Consult a qualified attorney or CPA before acting on any of them.
An oil & gas working interest reported on Schedule K-1 (Form 1065) rather than Schedule E is a different reporting regime: depletion is computed at the partner level, IDC passes through with separate elections, the § 761(a) election can opt the venture out of subchapter K entirely, and self-employment tax exposure differs from a directly held WI. Unlike a mineral or royalty interest — which bears no operating costs — a working interest carries capital and operating expense responsibility, which is what drives the K-1 mechanics. This post is the practitioner workflow.
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