An oil and gas DPP’s tax life cycle: a five-year worked example

A first-year deduction can change the economics of an oil and gas investment. Understanding the full result requires following what happens afterward: production revenue, operating costs, cash distributions, additional spending, and taxes when assets are sold.

For an investor evaluating a direct participation program, or DPP, these amounts belong in the same calculation. A deduction reduces taxable income. A distribution puts cash in the investor’s hands. They can occur in different years and differ substantially in size.

The following hypothetical example follows a $100,000 investment through five years. It includes a base case, a weaker operating case, and a case in which the initial deduction cannot be used immediately.

These figures are invented for explanation. They are not BassEXP performance results, projections, or the terms of a particular offering. The five-year period does not establish an expected well life or promise an exit.

The assumptions behind the example

The investor contributes cash to a hypothetical LLC taxed as a partnership that owns domestic oil and gas working interests. It is not a publicly traded partnership. Every amount shown represents this investor’s share of the program’s activity.

The investor’s participation is passive for tax purposes. In the base case, the investor has sufficient eligible ordinary passive income from other activities to use the initial loss. Basis, at-risk, and other applicable limitations do not restrict the deductions. The DPP label alone does not determine whether losses can offset wages or other income. IRS Publication 925

The remaining assumptions are:

• The $100,000 contribution funds $70,000 of qualifying intangible drilling costs, $20,000 of qualifying equipment, and a $10,000 cash reserve. There is no production income in Year 1.
• Eligible IDC is expensed. Equipment is acquired and placed in service when required for 100% federal bonus depreciation. The same treatment applies to a $5,000 equipment purchase in Year 4.
• There is no separate mineral or leasehold acquisition basis. No debt, special allocations, or fees beyond the stated expenditures are modeled. Operating costs include the assumed deductible operating and administration charges.
• The investor qualifies for 15% percentage depletion on the stated production income. Production limits, the property-income limit, and the separate 65% overall-income limit are satisfied. With zero depletable mineral basis, cost depletion is zero.
• Each usable deduction or taxable dollar changes regular federal income tax at an assumed constant 37%. State taxes, alternative minimum tax, net investment income tax, self-employment tax, and the qualified business income deduction are excluded.

Current federal rules are held constant across the five-year illustration. The equipment assumption reflects the rules for qualifying property acquired and placed in service after January 19, 2025. Eligibility still depends on the property and transaction. IRS Publication 946

The tax effects below are assigned to the year that generates them. Actual estimated payments, return filing, and refunds can occur on a different schedule.

Year one: $100,000 contributed, $90,000 deducted

The initial cash allocation is straightforward:

The reserve remains available to the program. Funding it creates no deduction by itself.

With no production income and the full loss currently usable, the modeled federal tax reduction is:

$90,000 × 37% = $33,300.

The investor still sends $100,000 to the partnership. The $33,300 represents a reduction in the investor’s modeled tax liability, not a payment from the program or a guaranteed refund.

Subtracting that tax effect produces a $66,700 net cash outflow for Year 1 in this illustration. That figure is not the investor’s tax basis.

Years two and three: production creates cash and taxable income

Production starts in Year 2. The operating assumptions decline over time:

Production income here means the investor’s allocated qualifying gross income after royalty burdens. It excludes asset-sale proceeds. All available operating cash is distributed, while the original $10,000 reserve remains untouched until Year 5.

In Year 2, $65,000 of production income less $25,000 of operating costs leaves $40,000 of cash. The investor receives that amount.

Percentage depletion reduces the taxable operating result by another $9,750, leaving $30,250. It does not require a corresponding cash payment that year. That explains why the investor receives $40,000 while the modeled taxable result is $30,250.

For oil and gas partnerships, the partner calculates depletion using information supplied by the partnership. It is not automatically 15% of the cash distribution. The rate and limits depend on eligibility and the underlying production information. IRS Schedule K-1 instructions, IRS Oil and Gas Audit Technique Guide

Year 3 follows the same approach: $30,000 distributed and $21,750 of taxable operating income after depletion. BassEXP’s depletion guide provides further background on the distinction between percentage and cost depletion.

Years four and five: additional equipment and lower revenue

In Year 4, production income falls to $45,000. After $22,000 of operating costs, the program spends $5,000 on new qualifying equipment.

The equipment is a capital asset. The model assumes full bonus depreciation after it is placed in service. It is not classified as IDC or an ordinary repair merely because the expenditure supports an existing well.

The purchase reduces distributable operating cash from $23,000 to $18,000. After equipment depreciation and $6,750 of depletion, the taxable operating result is $11,250. Operating cash funds the purchase, so no additional contribution is required.

Year 5 produces $15,000 of operating cash and $9,750 of taxable operating income before the asset sale. In an actual program, changes in prices, production, downtime, and costs could produce a very different pattern.

The Year 5 asset sale and recapture

At the end of Year 5, the partnership sells its underlying assets for cash and liquidates. This is an asset sale by the partnership, not the investor selling an LLC interest.

The investor’s share of the assumed sale price is $20,000, allocated on supported values as follows:

The mineral basis is zero under the initial assumptions. Equipment basis is zero after the modeled depreciation. No selling costs or remaining liabilities are assumed.

Prior deductions affect the gain’s character. The $15,000 mineral gain is ordinary income under the Section 1254 recapture rules, covered by the investor’s prior $70,000 IDC deduction. The $5,000 equipment gain is ordinary depreciation recapture under Section 1245. Oil and gas Section 1254 recapture requires partner-level calculations. IRS Form 4797 instructions, Treasury Regulation Section 1.1254-5

Thus, all $20,000 of sale gain is modeled at the same 37% ordinary rate. The sale does not make the entire original $90,000 deduction taxable again; the recapture calculation is limited by the applicable gain and recapture rules.

Year 5 cash distributions total $45,000: $15,000 from operations, $20,000 from the asset sale, and the $10,000 reserve. The taxable result is $29,750, comprising $9,750 of operating income after depletion and $20,000 of recapture gain.

Selling a partnership interest requires a different analysis, including potential ordinary-income treatment under Section 751. These asset-sale numbers should not be reused for that transaction. IRS Publication 541

The complete five-year cash and tax picture

The table combines the operating and sale assumptions. Positive tax effects represent tax reductions; parentheses represent cash outflows, tax payments, or losses.

*Total deductions include operating costs, IDC, equipment depreciation, and partner-level depletion, as applicable. They are already reflected in the net taxable result; do not subtract them again. The taxable-result rows combine relevant items and do not represent a single Schedule K-1 box. Year 5 includes the sale gain.

Over five years, the investor contributes $100,000 and receives $133,000. Pretax profit is $33,000.

The initial $33,300 modeled tax reduction is followed by $34,410 of modeled tax on later income. The net federal tax cost is $1,110, leaving $31,890 of profit after the modeled tax effects.

That is a cumulative dollar result, not an annualized return. It also excludes the tax interactions listed earlier.

Keep property basis separate from partnership basis

Property basis determines deductions and gain on the underlying assets. The investor’s basis in the partnership interest, often called outside basis, tracks a different asset.

Here, outside basis starts at $100,000 and falls to $10,000 after the Year 1 loss. It remains $10,000 at each year-end through Year 4 because subsequent basis increases from partnership income are matched by cash distributions.

The percentage depletion needs special treatment. Oil and gas depletion reduces outside basis only up to the investor’s allocated adjusted basis in the depletable property. Because that property basis is zero here, the percentage depletion neither reduces nor increases outside basis. IRS Publication 541

In Year 5, $15,000 of partnership operating income before depletion and $20,000 of sale gain increase outside basis from $10,000 to $45,000 before distributions. The final $45,000 cash distribution reduces it to zero, producing no additional distribution gain under these assumptions.

The $66,700 initial cash outflow after modeled tax therefore has no role as either property basis or outside basis.

What changes when revenue falls or deductions are delayed?

For the downside case, reduce production income by 25% in every producing year and reduce the asset-sale price from $20,000 to $10,000. Hold operating costs and equipment spending unchanged. The reduced sale price is allocated $7,500 to mineral property and $2,500 to equipment, with both gains fully subject to ordinary recapture.

For the delayed-deduction case, keep the base investment’s economics unchanged. Change only the investor’s available passive income: there is none from other activities, so the $90,000 Year 1 passive loss is suspended.

The downside investor still receives the initial tax benefit. Nevertheless, the investment loses $8,685 after all modeled federal tax effects. Tax deductions reduce the loss but do not make the investment profitable.

In the delayed case, suspended losses offset $30,250 in Year 2, $21,750 in Year 3, $11,250 in Year 4, and $26,750 in Year 5. That uses all $90,000, leaving $3,000 taxable in Year 5 and $1,110 of modeled tax.

Its nominal after-tax profit matches the base case because the rate stays constant and all losses are eventually used. The timing is different: the delayed investor funds the full $100,000 initially without a Year 1 tax reduction. Receiving a benefit later affects liquidity and its present value. Different future rates or losses that remain suspended could also change the total result.

Use the example to examine an actual DPP

Replace these assumptions with offering-specific information before using the model to evaluate an investment. Request:

• A complete use-of-funds schedule, including acquisition costs, fees, drilling, equipment, and reserves.
• Production, price, operating-cost, and distribution assumptions, including potential additional funding.
• Tax allocations, depletion information, and records supporting the relevant basis calculations.
• Exit assumptions that identify the transaction, selling costs, recapture, and any remaining plugging or other obligations.

Your CPA can then determine which deductions you could use, when you could use them, and how federal and state rules affect your cash flows.

BassEXP’s oil well investment returns guide offers broader context for evaluating project economics. To discuss the assumptions behind an available DPP, contact BassEXP and review the applicable offering documents alongside your tax adviser’s analysis.

This hypothetical illustration is educational and does not provide individualized tax or investment advice. Federal sources checked September 25, 2026.