The Short Answer
Intangible drilling costs (IDCs) are the part of an oil or gas well’s cost that has no salvage value: labor, fuel, drilling fluids, hauling, site preparation, and similar items. Under Internal Revenue Code §263(c) and its regulations, an eligible taxpayer may elect to deduct those costs in the year they are paid or incurred instead of capitalizing them.
For an investor who holds a working interest without limited liability, the resulting loss is generally not passive, so it may offset wages, business income, or other non-passive income. That is the reason the deduction comes up in year-end planning for accredited investors with a large income year. It also comes with real limits and real risks, which take up the second half of this guide.
This page explains a mechanism in the tax code. It does not describe any specific program, and nothing here is a promise of a tax result. Your CPA should confirm how any of it applies to your return.
What Counts as an Intangible Drilling Cost
Every well has two kinds of cost.
| Intangible drilling costs | Tangible drilling costs | |
|---|---|---|
| What they are | Costs consumed in the work, with no salvage value | Physical equipment that stays with the well and keeps some value |
| Examples | Labor, fuel, drilling mud and fluids, hauling, surveying, site preparation | Casing, tubing, pumps, wellhead and surface equipment |
| General tax treatment | May be deducted currently under the §263(c) election | Generally capitalized and recovered through depreciation |
The split matters because only the intangible portion qualifies for the current-year election. The share of a well’s budget that is intangible varies from well to well and from program to program, so there is no single percentage that applies to every investment. For tangible equipment, recent legislation restored 100% bonus depreciation for qualifying property acquired after January 19, 2025, which can accelerate that portion as well. Whether it applies depends on the property and on the program’s elections.
For a two-sentence version, see our glossary entry on intangible drilling costs.
How the Deduction Is Taken
The §263(c) election is made at the level of the operator or the entity that pays the costs, and it flows through to investors. In a partnership structure, each investor’s share of the deduction is reported on a Schedule K-1.
Timing follows the tax year in which the costs are properly paid or incurred under the tax rules and the program’s documents. A deduction intended for a given year generally requires the investment to be funded, and the drilling work to be under way, within the window those rules describe. A program’s documents set its own closing dates, which may come before December 31.
Taxpayers can also elect under §59(e) to amortize IDCs over 60 months instead of deducting them all at once. That choice can make sense for someone who would otherwise run into the alternative minimum tax, covered below.
The Working-Interest Exception to the Passive Loss Rules
Most investment losses fall under the passive activity rules of §469. Passive losses generally offset only passive income, and any excess carries forward.
Oil and gas has a specific exception. Under §469(c)(3), a working interest in an oil or gas property is not treated as a passive activity if the taxpayer holds it directly or through an entity that does not limit the taxpayer’s liability.
In practice, this is why many drilling programs offer an investor general partner interest alongside a limited partner interest:
- General partner-type interest. The investor’s liability is not limited during the drilling phase, so the loss is generally non-passive and may offset non-passive income.
- Limited partner or LLC member interest. Liability is limited, so the loss is generally passive and offsets only passive income.
The feature that makes the deduction non-passive is the same feature that exposes the investor to liability. One should never be weighed without the other. Programs often convert general partner interests to limited partner interests after drilling, and if a loss was treated as non-passive under this exception, later net income from the same property is generally treated as non-passive too.
Several other rules can limit how much of a loss an individual can use in one year, even when the interest is non-passive:
- Basis and at-risk limits (§465). A loss generally cannot exceed what the investor has at risk in the activity.
- The excess business loss limitation (§461(l)). For individuals, business losses above an annual threshold cannot offset non-business income in the current year. The disallowed amount carries forward. The 2025 tax legislation, commonly called the One Big Beautiful Bill Act (OBBBA), made this limitation permanent.
These are return-level questions, and they are the reason a CPA should run the numbers before anyone signs.
The Alternative Minimum Tax
Under §57(a)(2), part of an IDC deduction can be a tax preference item for the alternative minimum tax (AMT). In general terms, the preference is based on the amount by which the IDC deduction exceeds what would have been deductible had the costs been amortized over ten years, reduced by a portion of net income from oil and gas properties. Taxpayers who are not integrated oil companies get additional relief under the statute, subject to a limit.
OBBBA kept the higher AMT exemption amounts for individuals. Beginning in 2026, it also lowered the income levels at which the exemption starts to phase out and sped up the phase-out. A high-income taxpayer who was clear of the AMT in prior years should have their CPA check the current year again. The §59(e) 60-month election mentioned above is one way to remove the preference, at the cost of a slower deduction.
Recapture When the Interest Is Sold
The IDC deduction shifts when income is taxed, and a sale can bring part of it back. When oil or gas property is sold or otherwise disposed of, §1254 generally treats previously deducted IDCs as ordinary income, to the extent of the gain on the disposition. Depletion deductions can be recaptured the same way.
Put simply, a gain that might otherwise be capital gain can come back as ordinary income. Recapture is one more reason to treat these interests as long-term holdings, and to ask your CPA how a future sale or transfer would be taxed before you invest.
A Note on Depletion
Producing wells may also generate a depletion deduction. Independent producers and royalty owners may be able to use percentage depletion under §613A, subject to limits on quantity and on taxable income. Whether an individual partner qualifies depends on that partner’s own facts. Depletion only exists if a well produces, so it should never be counted on in advance.
Who the IDC Deduction Is Generally Relevant For
Direct oil and gas programs are generally private placements offered only to accredited investors through a private placement memorandum. The deduction tends to come up in conversations with people who:
- Have significant ordinary income, or a large one-time income year from a business sale, a bonus, or the sale of a concentrated position
- Can tie up capital for many years with no reliable way to sell
- Can accept the possibility of losing the entire investment
- Have a CPA who can model the deduction against their full return, including the passive loss, at-risk, excess business loss, and AMT rules
It is usually a poor fit for someone who needs liquidity, who is relying on the money for near-term goals, or whose interest in the investment rests on the tax deduction alone. An investment that loses money is a poor investment whatever the deduction was worth. Oil and gas is one of several tax-related categories an accredited investor might compare. Our guide to tax strategies for accredited investors covers others.
The Risks, Stated Plainly
Oil and gas investing is speculative. Each of the following applies, and anyone considering an investment should read the offering documents in full.
- Loss of principal. Wells can be dry or produce far less than expected. You can lose some or all of the money you invest.
- Commodity price risk. Oil and natural gas prices move sharply with global supply and demand, and revenue from a well moves with them.
- Production decline. Output from a well generally falls over time, often steeply in the early years.
- Illiquidity. Interests are generally not transferable and have no public market. Plan to hold them for the life of the program.
- Liability exposure. Interests that carry general partner-type liability, the kind that make the deduction non-passive, can expose the investor to liabilities during drilling beyond the amount invested. Programs typically address this with insurance and other measures, which have limits.
- Operational and environmental risk. Drilling accidents, equipment failures, cost overruns, and environmental liabilities can all reduce or eliminate value.
- Fees and conflicts. Programs carry sponsor and offering costs that reduce the amount actually put into the ground. They are described in each offering’s documents.
- Tax risk. The deduction depends on the program’s structure, the investor’s own tax situation, and current law. Congress can change the rules, the IRS can challenge a position, recapture can apply on a sale, and state treatment varies.
Questions to Take to Your CPA
- Would an interest I am considering be passive or non-passive for me, given the structure?
- How much of a first-year deduction could I actually use after the basis, at-risk, and excess business loss limits?
- Would the deduction create or increase AMT for me this year, and should I consider the §59(e) election?
- How would a future sale, transfer, or conversion of the interest be taxed, including §1254 recapture?
- How does my state treat the deduction?
Talk It Through
Grace Capital Management is an independent advisory firm in Austin. We work with accredited investors who are evaluating how categories such as oil and gas programs, Delaware Statutory Trusts, 1031 exchange replacement structures, and opportunity zone funds might fit a specific tax picture, working alongside the client’s CPA. Grace’s representatives may receive compensation when a client invests, which is a conflict of interest you should weigh, and the costs are described in each offering’s documents. If you would like to talk through whether the category deserves a closer look, start a conversation or call Earl Proeger at (512) 293-7731.
This guide is educational only and is not tax, legal, or investment advice. It describes general federal tax rules as the author understands them as of its date; tax law can change, state treatment varies, and individual results depend on each taxpayer’s facts. Oil and gas programs are speculative, illiquid private placements available only to accredited investors and offered only by private placement memorandum. They involve substantial risk, including the possible loss of the entire investment, and distributions are not guaranteed. Nothing on this page is an offer to sell or a solicitation of an offer to buy any security. Consult your tax professional and attorney about your own circumstances. Securities offered through Concorde Investment Services, LLC (CIS), member FINRA/SIPC. Advisory services offered through Grace Capital Management, LLC, an SEC-registered investment adviser. Grace Capital Management and Concorde Investment Services, LLC are not affiliated entities. CIS does not provide tax or legal advice.