Oil and gas taxation has its own vocabulary and its own set of deductions unavailable to other industries. The two most significant: depletion (the recovery of capital invested in a natural resource - analogous to depreciation but calculated differently) and intangible drilling costs (IDCs - the immediate expensing of drilling expenditures that have no salvage value). Together, these provisions allow oil and gas investors to recover a substantial portion of their investment in the year it is made, making oil and gas one of the most tax-advantaged investment classes in the Code for the right investor profile.
Intangible Drilling Costs (IDCs): Labor, chemicals, mud, grease, and other costs incurred in drilling a well that have no salvage value are immediately deductible under IRC §263(c) in the year paid or incurred. For a working interest owner, this is typically 70-80% of the total well cost. A $1 million well investment may generate $700,000-$800,000 of current-year deductions.
Percentage Depletion: Independent oil and gas producers can deduct 15% of gross income from the property each year as depletion - regardless of the investor's actual cost basis. Percentage depletion can exceed the property's cost basis over time, creating deductions after the full investment has been recovered. Integrated oil companies (majors) may not use percentage depletion.
Every owner of an economic interest in oil and gas property is entitled to a deduction for depletion as the resource is extracted. There are two methods:
Cost depletion (IRC §611): The adjusted basis of the property is allocated across estimated total reserves. Each year's depletion equals (units extracted / total estimated units) x adjusted basis. Cost depletion ends when the full basis has been recovered.
Percentage depletion (IRC §613A): Independent producers and royalty owners may deduct 15% of gross income from the property, limited to 100% of the net income from the property. Unlike cost depletion, percentage depletion is not limited by the property's basis - it can continue indefinitely, generating deductions that cumulatively exceed the original investment. The independent producer limitation: percentage depletion applies only to the first 1,000 barrels of average daily production (or equivalent for gas). Production above that level is limited to cost depletion.
Intangible drilling and development costs - expenditures that are incidental to drilling and that have no salvage value - are immediately deductible under IRC §263(c) and Treas. Reg. §1.612-4. IDCs include: labor costs, fuel, repairs, hauling, supplies used in drilling and preparation of wells for production. They do not include tangible equipment with salvage value (casing, tubing, wellheads) - those are capitalized and depreciated under MACRS.
For corporations, the IDC deduction may be a preference item for alternative minimum tax purposes (though the TCJA corporate AMT was replaced with the corporate alternative minimum tax (CAMT) under OBBBA). Individuals who are working interest owners (not limited partners or passive investors) may deduct IDCs in full against ordinary income in the year incurred.
Under IRC §469(c)(3), a working interest in an oil and gas property held directly or through an entity that does not limit liability (such as a general partnership) is not treated as a passive activity - regardless of whether the taxpayer materially participates. This means IDC deductions and other losses from a working interest can offset wages, portfolio income, and other active income without passive activity limitation. The exception applies only to working interests - royalty interests, overriding royalty interests, and production payments are passive by default and subject to the normal §469 rules.
The §45 production tax credit (PTC) was significantly expanded and extended by recent legislation. For oil and gas, the relevant credits include: the §45I credit for natural gas production from marginal wells, and various clean energy production credits for facilities that capture methane or produce hydrogen from natural gas. OBBBA modified some energy credit provisions - practitioners should verify the current credit rates and placed-in-service requirements before advising on specific energy investments, as these provisions changed multiple times between 2022 and 2025.