Oil depletion allowance ongoing tax deduction on producing Texas well

Oil Depletion Allowance: The Provision That Outlasts Your Original Investment

Most tax deductions in the code are bounded. You depreciate equipment until it's fully depreciated. You deduct contributions up to the plan limit. You deduct interest until the loan is paid off. The oil depletion allowance under IRC §613A has no such boundary. You deduct 15% of gross oil and gas production income every year — continuing even after your cumulative depletion deductions have exceeded your original investment many times over. This is not a loophole or a technicality. Congress deliberately designed percentage depletion to continue beyond cost recovery because the policy rationale is not recovering cost — it's acknowledging that a finite natural resource is being permanently extracted and depleted. The resource doesn't stop being depleted when you've recovered your investment. So the deduction doesn't stop either.

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15%

Annual depletion deduction

§613A

IRC provision

No end

Continues beyond cost recovery

~31.5%

Effective rate at 37% bracket

Percentage Depletion vs. Cost Depletion: Which Applies to Investors

Two depletion methods exist under the tax code. Cost depletion allocates the original investment cost across the estimated reserves — as you extract a barrel, you deduct the proportionate share of cost assigned to that barrel. When the full cost is allocated, depletion ends. This is analogous to depreciation.

Percentage depletion is different in kind. You deduct a fixed percentage of gross income — regardless of your cost basis, regardless of whether you've fully recovered your investment, and regardless of how much the well has produced relative to original reserve estimates. For independent oil and gas producers, the statutory rate under §613A is 15% of gross income from the property. See oil & gas tax deductions for the complete four-provision framework.

Factor	Cost Depletion	Percentage Depletion (§613A)
Basis	Original investment cost	15% of gross production income
Ends when?	Full cost recovered	Never — continues indefinitely
Calculation	(Cost ÷ Estimated reserves) × units produced	15% × gross income from property
Better for investors?	Rarely — ends at cost recovery	Yes — continues beyond cost recovery
Who uses it	When cost depletion > percentage depletion	Independent producers (virtually always the better method)

Illustrative example only. Actual tax savings and investment returns depend on individual circumstances including tax bracket, AMT exposure, state tax treatment, program structure, and well performance. Not a projection or guarantee of results. Consult a qualified CPA before making any investment decision.

The Mechanics: What 15% Means Year by Year

Percentage depletion is calculated on gross production income from the property — the revenue from oil and gas sales attributed to your working interest, before deducting operating costs. Your depletion deduction is 15% of that gross figure.

Example: Your working interest generates $48,000 in gross production income in Year 3 (your NRI share of gross oil and gas sales). Your depletion deduction is $7,200 (15% × $48,000). At the 37% federal bracket, this saves $2,664 in federal taxes. Your effective tax rate on that $48,000 of production income is 37% × 85% = 31.45%.

The depletion deduction cannot exceed 100% of the net income from the property before depletion — so if operating costs consume most of the revenue, the depletion deduction is bounded by net income. More practically relevant: percentage depletion cannot exceed 65% of the taxpayer's total taxable income from all sources (before depletion). For most high-income investors, the 65% limit is never binding.

The Continuing-Beyond-Basis Advantage: The Long Math

Here is what makes percentage depletion categorically different from depreciation. Assume a $200,000 working interest investment. Through IDC deductions and TDC bonus depreciation, you fully recover your $200,000 cost basis in Year 1. Your adjusted basis in the working interest is now zero. With depreciation, the deductions end here. With percentage depletion, they don't.

The $29,600–$37,000 in cumulative federal savings from depletion alone — on a $200,000 investment that already generated $74,000 in Year 1 deduction savings — is the long-tail benefit competitors rarely explain. The total 25-year federal tax benefit from a single working interest investment at these illustrative levels exceeds $100,000 in federal tax savings. For the full year-by-year model, see tax benefits of oil investments.

Period	Annual Depletion (illus.)	Federal Savings/yr	Cumulative Savings
Years 1–5	~$9,000–$7,000/yr	~$3,330–$2,590/yr	~$14,600
Years 6–10	~$5,500–$4,000/yr	~$2,035–$1,480/yr	~$23,400
Years 11–15	~$3,000–$2,200/yr	~$1,110–$814/yr	~$28,200
Years 16–25	~$1,800–$900/yr	~$666–$333/yr	~$33,200

Depletion and the NIIT: Why Working Interest Outperforms Royalty

Both working interests and royalty interests qualify for the 15% depletion allowance. But the two structures receive different treatment from the Net Investment Income Tax (NIIT).

Royalty income is passive. For single filers with MAGI above $200,000 and joint filers above $250,000, passive investment income (including royalties) is subject to a 3.8% NIIT surcharge on top of the ordinary income rate. After depletion: 37% × 85% + 3.8% = approximately 35.25% effective rate on royalty production income.

Working interest production income is active under §469(c)(3). Active income is not subject to NIIT. After depletion: 37% × 85% = 31.45% effective rate. The working interest advantage over royalty: 3.8 percentage points per dollar of production income, every year, for the life of the well. See our royalty vs working interest comparison.

AMT Treatment: Depletion in Excess of Basis

Percentage depletion in excess of the adjusted basis of the property is a preference item under §57(a)(1) for AMT purposes. In practical terms: in the early years of a well, your adjusted basis is positive (your original investment minus the IDC deduction already taken). Depletion taken within that positive basis is not an AMT preference. Once cumulative depletion deductions exceed your adjusted basis — which, for a fully IDC-expensed working interest, occurs relatively early in the well's life — excess depletion becomes an AMT preference item. For most investors who are not in the AMT phase-out zone, this preference item is irrelevant because regular tax exceeds the tentative minimum tax regardless.

Frequently Asked Questions

What is the oil and gas depletion allowance?

The depletion allowance is a tax deduction that recognizes the gradual exhaustion of an oil well as a natural resource. For independent producers under §613A, percentage depletion allows 15% of gross production income to be deducted annually — permanently reducing the effective tax rate on oil and gas income for the life of the well.

Does the depletion allowance apply to both working interests and royalties?

Yes. Percentage depletion under §613A applies to both working interest owners and royalty owners who qualify as independent producers. The same 15% rate applies to both structures. The key difference is that working interest owners also receive the Year 1 IDC deduction — a benefit royalty owners do not have.

Does percentage depletion stop when the well's cost is fully recovered?

No — this is one of the most advantageous features of the percentage depletion allowance. Unlike cost depletion (which ends when the adjusted basis reaches zero), §613A percentage depletion continues for the productive life of the well regardless of cost recovery. A well that has fully paid back its investment still generates a 15% depletion deduction on every barrel of production income in Year 20.

Is the depletion allowance available to large oil companies?

No. The percentage depletion allowance for domestic production was eliminated for major integrated oil companies in 1975. It is available only to independent producers and royalty owners — not to refiners, retailers, or companies exceeding 1,000 barrels of daily production per shareholder. Private investor programs structured through qualified entities preserve this independent producer exemption.

How does the depletion allowance interact with the Alternative Minimum Tax?

Percentage depletion is an AMT preference item under §57(a)(1) to the extent it exceeds the adjusted basis of the property. In early production years when depletion has not yet exceeded the original investment, the AMT issue typically doesn't arise. In later years when cumulative depletion exceeds basis, the excess depletion amount requires a Form 6251 addback. Your CPA should track the basis annually.

The Historical Context: Why Depletion Exists

Percentage depletion for oil and gas was first introduced in 1926, when Congress recognized that oil wells are finite assets — unlike a factory that can be maintained indefinitely, an oil reservoir depletes with every barrel produced. The depletion allowance was designed to let producers recover some of their investment tax-free, incentivizing continued domestic production. The 1975 Tax Reform Act eliminated percentage depletion for major integrated oil companies but preserved it for independent producers — which is why §613A exists as a separate provision from §611. This distinction has been explicitly reaffirmed by Congress in every major tax reform since 1975, including the Tax Cuts and Jobs Act of 2017 and the One Big Beautiful Bill Act of 2025.

Percentage Depletion vs. Cost Depletion: The Practical Decision

Investors can choose between two depletion methods in any given year: percentage depletion (15% of gross income) or cost depletion (based on remaining adjusted basis divided by estimated recoverable reserves). In practice, percentage depletion is almost always larger for private working interest investors — and the rules allow you to use whichever is greater.

	Percentage Depletion (§613A)	Cost Depletion (§611)
Calculation basis	15% of gross production income	Remaining basis ÷ estimated reserves
Continues beyond basis?	Yes — indefinitely	No — ends when basis reaches zero
Affected by IDC deduction?	No — independent of basis	Yes — IDC reduces basis, reducing depletion
Who qualifies	Independent producers only	All producers
Verdict for private investors	Almost always larger — use this	Fallback only

The 100% Net Income Cap: The One Limitation That Matters

Percentage depletion cannot exceed 100% of the net income from the property in any year. This means if your working interest generates $10,000 in gross production income and $9,500 in LOE — net income of $500 — your depletion deduction is capped at $500, not $1,500 (15% of gross). In practice, this cap rarely binds in early production years when production rates are highest relative to LOE. It becomes more relevant in Years 15–25 when production has declined significantly.

Depletion in Programs Offered Through Our Partner Network

Working interest programs offered through Texas Oil Investments' industry partner network are structured to qualify for percentage depletion under §613A. This requires the program entity to qualify as an independent producer — which it does when it is not an integrated oil company, not a retailer, and does not refine more than 50,000 barrels per day. The depletion calculation for each investor's share is performed by the program's accountants and reported on the annual Schedule K-1 supplemental depletion schedule. This is one of the items your CPA should review when preparing your return.

Disclaimer

The information on this page is for educational purposes only and does not constitute investment advice, tax advice, or legal advice. Oil and gas working interest investments involve significant risks including commodity price volatility, geological risk, operational risk, and potential loss of entire invested capital. All tax benefit descriptions reference IRC provisions as currently in effect; tax law is subject to change and individual tax treatment varies. All dollar examples and projections are illustrative only — not representations of actual returns. Programs are offered exclusively to verified accredited investors as defined by SEC Rule 501, under SEC Regulation D Rule 506(b). This page does not constitute an offer to sell or solicitation of an offer to buy any security. Consult a qualified CPA, attorney, and financial advisor before making any investment decision.

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Oil & Gas Tax Deductions Intangible Drilling Costs Tax Benefits of Oil Investments High Income Earner Strategies Year-End Tax Planning Royalty vs Working Interest OBBBA Analysis Passive Income from Oil Wells

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