Working Interests in Oil and Gas: What Investors Need to Know
Cost obligations, revenue mechanics, tax benefits, and risk considerations for working interest investors
Key Takeaway
A working interest in oil and gas obligates the holder to pay a proportional share of all drilling and operating costs in exchange for a larger share of production revenue. Working interests offer significant tax advantages, including potential first-year IDC deductions that can shelter income from taxes. Most accredited investors access working interests through limited partnership programs, where liability is capped at the amount invested and IDC deductions offset passive income. Investors who hold directly or through a general partnership may qualify for active income treatment under IRC Section 469(c)(3), but this carries unlimited personal liability. Working interests are generally not eligible for 1031 exchanges. Consult a qualified tax professional to evaluate how these benefits apply to your situation.
What Is a Working Interest in Oil and Gas?
A working interest in oil and gas is an ownership stake in a lease that gives the holder the right to explore, drill, and produce hydrocarbons from the property. Unlike passive ownership structures, a working interest also obligates the holder to pay a proportional share of all costs associated with the well, including drilling, completion, and ongoing operations.
This cost-bearing characteristic is what sets working interests apart from royalty interests and other passive positions. Royalty owners receive income from production without contributing to expenses. Working interest holders, by contrast, fund the actual exploration and production activity. This is how most oil and gas drilling programs are capitalized.
After royalty burdens are paid (typically 12.5% to 25% of gross production), the remaining 75% to 87.5% of revenue is distributed among working interest owners in proportion to their ownership percentage. The revenue share is larger than what royalty holders receive, but it comes with real financial obligations. Working interest investments are most commonly structured as limited partnership programs offered by sponsors, where the sponsor and operator handle all drilling, production, and compliance decisions while accredited investors participate in revenue and tax benefits without managing day-to-day operations.
Operating vs. Non-Operating Working Interests
Operating Working Interest
The operator is the working interest owner who manages the day-to-day drilling and production activity on a lease. This includes hiring contractors, directing well operations, ensuring regulatory compliance, and handling environmental obligations. The operator typically holds the largest ownership stake in the well and is often the entity that proposed the drilling program.
Operating working interest holders bear unlimited liability for well operations. This extends to environmental cleanup costs, well plugging and abandonment obligations, and third-party damages. The operator is also responsible for billing other working interest owners for their share of costs and managing the joint account.
Non-Operating Working Interest (NOWI)
A non-operating working interest is an ownership position where the holder pays their proportional share of drilling, completion, and operating costs but does not manage daily well operations. The operator handles all operational decisions on behalf of all working interest owners.
Non-operating working interest holders still carry financial risk. They pay their share of costs and receive their share of revenue, just as the operator does. However, their liability exposure is generally limited to their proportional cost obligations rather than the broader operational liabilities the operator assumes.
This is the most common structure for investors participating in oil and gas programs. It is important to understand that a non-operating working interest is not the same as a royalty interest. Non-operating working interest owners are still obligated to pay costs. Royalty owners are not.
How Working Interest Income and Expenses Work
Revenue Distribution and Net Revenue Interest
Gross production revenue from a well is first reduced by royalty burdens. These include the landowner's royalty and any overriding royalties that have been assigned. The revenue remaining after royalties is then split among working interest owners based on their ownership percentages.
The metric that captures a working interest owner's actual share of revenue is called net revenue interest (NRI). NRI equals the working interest percentage multiplied by the revenue remaining after royalty burdens. For example, an investor who owns a 25% working interest in a lease with a 20% total royalty burden would have an NRI of 20% (25% multiplied by 80%). This 20% represents their share of gross production revenue before operating expenses.
Monthly revenue distributions fluctuate based on two variables: production volumes and commodity prices. Early months of production typically generate the highest volumes, with output declining along a predictable curve over the life of the well.
Joint Interest Billing (JIB), AFEs, and Cash Calls
Working interest owners interact with the operator through several financial mechanisms. A joint interest billing statement (JIB) is a monthly document from the operator that itemizes each owner's proportional share of operating costs, including pumping, maintenance, compression, and water disposal.
Before any major capital expenditure, the operator issues an Authority for Expenditure (AFE). This is a detailed cost estimate for a proposed activity such as drilling a new well, performing a workover, or completing a zone. Working interest owners review the AFE and decide whether to participate.
Cash calls are the operator's requests for working interest owners to fund their share of approved expenditures. These payments are due in advance of the work being performed.
If a working interest owner declines to participate in an approved operation, they may face a non-consent penalty. Under most joint operating agreements, consenting parties fund the non-consenter's share and recover 200% to 500% of that cost from the non-consenter's share of future production before the non-consenter begins receiving revenue again.
Working Interest vs. Royalty Interest: Key Differences
Understanding the distinction between a working interest and a royalty interest is essential for evaluating oil and gas investment opportunities. These two ownership structures differ in cost obligations, revenue share, risk profile, tax treatment, and level of involvement. For investors comparing oil and gas working interest vs. royalty interest structures, the table below summarizes the primary differences.
| Factor | Working Interest | Royalty Interest |
|---|---|---|
| Pays drilling/operating costs | Yes | No |
| Revenue share | 75-87.5% (after royalty) | 12.5-25% (or per lease) |
| Liability exposure | Yes (unlimited for OWI) | None |
| Management involvement | Active or semi-active | Fully passive |
| Tax deductions available | IDCs, operating costs, depletion | Depletion only |
| 1031 exchange eligible | Generally no | Mineral rights: yes |
Economics and Cash Flow
Working interest owners receive a larger share of production revenue, but that revenue is offset by drilling, completion, and operating costs. Net cash flow depends heavily on well productivity, operating efficiency, and commodity prices. In a weak price environment or with a marginal well, costs can exceed revenue.
Royalty interest owners receive a smaller percentage of gross revenue but bear no costs. Their net income is more predictable because there are no expense offsets.
Risk and Liability
Working interest holders are exposed to dry hole risk, cost overruns beyond AFE estimates, and (for operating working interests) direct environmental and operational liability. Royalty interest holders carry none of these risks. Their exposure is limited to production decline and commodity price fluctuations.
Tax Treatment
The tax treatment of working interests vs. royalty interests differs significantly. Working interest owners can deduct intangible drilling costs (up to 100% in the year incurred for active participants), operating expenses, and depletion allowances. Royalty interest owners are limited to depletion deductions only. They cannot deduct drilling costs or operating expenses.
This tax asymmetry is one of the primary reasons high-income investors choose working interests despite the greater risk. The ability to deduct IDCs against active income can generate significant first-year tax savings. Investors evaluating the tax implications of selling investment property should consider how working interest deductions interact with their overall tax position.
Level of Involvement
Working interest owners participate in operational decisions. They receive AFEs, review JIBs, respond to cash calls, and decide whether to participate in new operations. This requires ongoing attention and financial commitment.
Royalty interest owners receive production checks with no operational involvement required.
An overriding royalty interest (ORRI) is worth noting in this comparison. An ORRI is carved out of the working interest, not the mineral estate. It behaves like a royalty interest (cost-free revenue) but is created by assignment from a working interest holder. The overriding royalty interest vs. working interest distinction matters because an ORRI reduces the net revenue available to working interest owners while providing a cost-free income stream to the ORRI holder.
Tax Benefits of Working Interest Investments
Working interest oil and gas investments carry some of the most significant tax advantages available to individual investors, stemming from specific Internal Revenue Code provisions for oil and gas exploration and production. Investors should consult a qualified tax advisor for guidance specific to their situation.
Intangible Drilling Cost (IDC) Deductions
Intangible drilling costs represent 60% to 80% of total well drilling costs. IDCs include labor, chemicals, drilling mud, site preparation, and other expenses that have no salvage value. Active working interest participants can deduct 100% of IDCs in the year they are incurred.
This front-loaded deduction is one of the most valuable tax benefits in oil and gas investing. An investor who commits $200,000 to a drilling program where 70% of costs are IDCs can potentially deduct $140,000 against income in the first year.
Operating Expense Deductions
Ongoing costs of production, including pumping, equipment maintenance, workovers, and transportation, are deductible as ordinary business expenses. These deductions are taken against working interest income in the year the costs are incurred, reducing taxable income from the investment on an ongoing basis.
Depletion Allowances
Depletion is the oil and gas equivalent of depreciation. Two methods are available. Cost depletion recovers the investor's original basis in the property as reserves are extracted, calculated as a ratio of units produced to total estimated recoverable units. Percentage depletion allows qualifying small producers to deduct 15% of gross income from the property. Percentage depletion is subject to limitations: it cannot exceed 100% of net income from the property or 65% of the taxpayer's overall taxable income. To qualify, a producer's average daily production must not exceed 1,040 barrels of oil equivalent.
Active Participation and Passive Loss Rules
How IDC deductions are classified for tax purposes depends entirely on how the working interest is held. There are three common structures, each with different tax treatment and liability implications.
Limited partnership programs (most common). Most accredited investors access working interests through limited partnership programs offered by sponsors. As a limited partner, the investor's liability is capped at the amount invested. IDC deductions are classified as passive losses, meaning they can offset income from other passive investments such as DST distributions, rental property income, or other limited partnership income. Passive IDC deductions cannot offset W-2 wages or active business income. Any unused passive losses carry forward indefinitely to offset future passive income. This structure is the most accessible path for investors who want working interest tax benefits with limited liability.
Direct or general partnership holding. Under IRC Section 469(c)(3), a working interest held directly or through a general partnership (not a limited partnership) is exempt from passive activity loss limitations. This means IDC deductions and operating losses can offset active income, including W-2 wages and business income. However, this treatment requires the investor to accept unlimited personal liability for all partnership obligations, including capital calls, plugging and abandonment costs, environmental remediation, and obligations incurred by other general partners. Joint and several liability means a creditor can pursue any individual general partner for the full amount of a partnership obligation. This structure is less common for retail investors due to the liability exposure.
Investor General Partner (IGP) election. Some programs offer a hybrid option where the investor initially holds as a general partner to access active income treatment, with an automatic conversion to limited partner status after drilling capital is deployed. This provides the active income offset during the period when IDC deductions are generated, then transitions to limited liability for the ongoing production phase. However, obligations incurred during the general partner period may survive the conversion. Investors considering this option should consult both a CPA (to confirm the tax treatment) and an attorney (to evaluate the liability exposure) before electing IGP status.
Risks of Working Interest Investments
Working interest investments carry meaningful risks that must be weighed against the potential returns and tax benefits. No investment in oil and gas production offers guaranteed outcomes.
Unlimited Liability (Operating WI)
Direct working interest holders and general partners can be held personally liable for environmental remediation, well plugging and abandonment costs, and third-party damages arising from well operations. This liability is unlimited and extends beyond the amount invested. Investors accustomed to evaluating risk in other investment structures will find that direct working interest liability exposure is considerably broader.
Investors who participate through limited partnership programs have their liability capped at the amount of their investment (plus any undistributed profits). They are not exposed to capital calls, environmental remediation, or the personal liability that applies to general partners and direct holders. This liability protection is one of the primary reasons most accredited investors access working interests through LP-structured programs rather than holding directly.
Capital Calls and Dry Hole Risk
Cash calls can arrive at any time if well operations require additional capital beyond the original AFE estimate. Investors should maintain reserves to meet these potential obligations.
Dry holes produce no commercial revenue, but the costs of drilling are still incurred. The IDC deduction provides some tax offset for this loss, but the invested capital is not recovered. Even productive wells experience declining output over time. Production decline curves mean that early-year returns are typically the strongest, with revenue tapering as reservoir pressure decreases and water production increases.
Commodity Price Exposure
Working interest revenue is directly tied to the spot prices of oil and natural gas. A sustained decline in commodity prices can turn a previously profitable well into a money-losing operation where costs exceed revenue. Some operators use hedging strategies to manage price risk, but these protections are not always passed through to individual working interest holders. Monthly production revenue will fluctuate, and there is no guaranteed income stream.
Who Should Consider Working Interest Investments?
Working interest investments suit two distinct investor profiles depending on the structure chosen. Investors with high active income (physicians, attorneys, executives, business owners) who want to offset W-2 or business income may evaluate programs with a general partner or IGP election, accepting the unlimited liability trade-off in exchange for active income treatment. This is a narrower group of investors who are comfortable with personal liability exposure and should work closely with both a CPA and attorney.
A broader group of accredited investors can access working interest tax benefits through limited partnership programs without the liability concerns. LP investors receive potential IDC deductions that shelter passive income from DST distributions, rental properties, and other passive investments, while the sponsor and operator handle all drilling and production decisions. Through Anchor1031, investors can access vetted LP programs where the operational burden is managed by the sponsor, making working interest ownership accessible without the complexity of sourcing and managing a direct position.
Both structures require a tolerance for illiquidity and volatility. Working interests cannot be easily sold on a secondary market, and monthly cash flow is unpredictable. Investors should be comfortable with the possibility that a well may underperform or produce no revenue at all.
Working interest ownership provides exposure to oil and gas production economics, which appeals to investors who want commodity-backed income alongside potential tax benefits. This is a different approach from passive structures such as mineral royalties or alternative investment vehicles like Delaware Statutory Trusts.
For investors considering a 1031 exchange, working interests are generally not eligible for tax-deferred exchanges under most program structures. Investors seeking tax-deferred exchanges should evaluate mineral rights or other qualifying real property interests instead.
Working interests in oil and gas programs are typically structured as securities offerings. Investors should work with a qualified financial advisor and tax professional before committing capital.
Next Steps
Understanding the mechanics, tax treatment, and risks of working interests helps investors determine whether this structure aligns with their financial goals and risk tolerance. Anchor1031 offers access to both working interest programs and royalty interest programs, giving investors the ability to choose the structure that best fits their objectives.
Working interest programs available through Anchor1031 are structured as limited partnerships, providing potential IDC deductions and depletion benefits with limited liability. Investors who want to evaluate whether active income treatment through a general partner or IGP election is appropriate for their situation can discuss the options and trade-offs with the Anchor1031 team.
Current Oil & Gas Programs
Available through Anchor1031 for accredited investors
Waveland Resource Partners VIII
Diversified portfolio of working interests and mineral interests in premier U.S. basins operated by leading energy companies.
Waveland Energy Partners
Inwood Minerals LLC
Direct-title mineral and royalty interests in income-producing oil and gas properties across three states.
Montego Energy Partners
Frequently Asked Questions
What is the difference between a working interest and a royalty interest in oil and gas?
A working interest owner pays a proportional share of drilling and operating costs and receives a larger share of production revenue (75% to 87.5% after royalties). A royalty interest owner receives a smaller share of gross revenue (typically 12.5% to 25%) with no cost obligations. Working interest holders bear operational and financial risk. Royalty holders do not.
Can you do a 1031 exchange with a working interest?
Generally, no. Working interests in most program structures are classified as interests in a trade or business rather than as qualifying real property for purposes of Section 1031. Mineral rights and certain royalty interests do qualify for 1031 exchanges. Investors should consult a tax advisor to evaluate exchange eligibility for their specific holding structure.
What is a non-operating working interest?
A non-operating working interest is an ownership stake in an oil or gas lease where the holder pays their proportional share of all costs but does not manage daily well operations. The designated operator handles all drilling, production, and compliance decisions. This is the most common structure for investors in oil and gas direct participation programs.
Are working interest tax deductions limited by passive loss rules?
It depends on the ownership structure. Most investors access working interests through limited partnership programs, where IDC deductions are classified as passive losses that can offset income from DSTs, rental properties, and other passive investments. For investors who hold directly or through a general partnership (not a limited partnership), losses may be exempt from passive activity limitations under IRC Section 469(c)(3), allowing deductions to offset active income such as wages and business income. However, this active income treatment requires the investor to accept unlimited personal liability. Some programs offer an Investor General Partner election that provides active treatment initially, then converts to limited partner status after capital deployment. Consult a qualified tax advisor to evaluate which structure is appropriate for your situation.
How much can you deduct in intangible drilling costs?
Active working interest participants can generally deduct 100% of intangible drilling costs in the year they are incurred. IDCs typically represent 60% to 80% of total drilling costs, covering items like labor, chemicals, and site preparation. Consult a tax advisor for guidance specific to your situation.
About the Author
Thomas Wall, Partner
Thomas Wall is a Partner at Anchor1031, where he specializes in educating clients about 1031 exchanges, private real estate offerings, and REITs. With nearly a decade of experience in alternative investments and real estate, Mr. Wall has helped investors through hundreds of 1031 exchanges, placing over $230M of equity into real estate.
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Disclosure
Tax Complexity and Investment Risk
Tax laws and regulations, including but not limited to Internal Revenue Code Section 1031, bonus depreciation rules, cost segregation studies, and other tax strategies, contain complex concepts that may vary depending on individual circumstances. Tax consequences related to real estate investments, depreciation benefits, and other tax strategies discussed herein may vary significantly based on each investor's specific situation and current tax legislation. Anchor1031, LLC and Great Point Capital, LLC make no representation or warranty of any kind with respect to the tax consequences of your investment or that the IRS will not challenge any such treatment. You should consult with and rely on your own tax advisor about all tax aspects with respect to your particular circumstances. Please note that Anchor1031 and Great Point Capital, LLC do not provide tax advice.
The information contained in this article is for general educational purposes only and does not constitute legal, tax, investment, or financial advice. This content is not a recommendation or offer to buy or sell securities. The content is provided as general information and should not be relied upon as a substitute for professional consultation with qualified legal, tax, or financial advisors.
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