This page is a disclosure, not a sales document. Each risk below is stated on its own, without a reassurance attached to it. If a risk here would be unacceptable to you, that is the correct conclusion to draw — not something to be argued out of.
Oil and gas drilling programs are speculative and illiquid. You should be prepared to lose your entire investment.
And read the next sentence carefully, because it is the one most often left out: depending on how you hold a working interest, your exposure may not be limited to the amount you invest. Consult your own attorney, CPA, and financial advisor before committing capital. Nothing on this page is legal, tax, or investment advice.
Note on a previous version of this page. Each risk below used to be followed by a “Mitigation” line that neutralised it, together with figures — operator well counts, decline rates, break-even prices, and a worst-case tax-savings estimate — that were published without sources. The mitigation lines have been removed so the risks stand on their own, and the unsourced figures have been removed rather than restated. Where risk-management measures are described at the end of this page, their limits are described with them. Ask us for the underlying data on anything you want verified, and verify it independently.
These four are the ones that distinguish a direct working interest from almost any other private investment. Three of them were previously absent from this page entirely.
A working interest is an ownership interest in oil and gas operations, not a passive security. A direct working-interest owner is a principal in those operations and can be held personally responsible for their consequences — including operating costs, contractual obligations to service providers, personal-injury claims, pollution and spill events, regulatory penalties, and plugging obligations.
This is the flip side of the tax benefit this industry markets hardest. IRC §469(c)(3) excepts working-interest losses from the passive-activity loss rules — letting them offset wages and other ordinary income — but only where the interest is held in a form that does not limit the holder's liability. You cannot claim the exception and cap the exposure at the same time. Holding through an entity that limits liability generally forfeits the treatment.
Insurance is customarily carried at the operations level, but policies have limits, deductibles, and exclusions, and may not respond to every claim. Ask what coverage exists, at what limits, and whether you are named as an additional insured. Discuss the holding form with your attorney and CPA before you subscribe — it cannot be fixed afterwards.
Working interests are commonly assessable. Beyond your initial subscription you can be invoiced for your proportionate share of costs, including:
These are frequently netted from revenue first — so a distribution can go to zero — and where the cost exceeds revenue, a bill follows. Non-payment under a joint operating agreement typically triggers non-consent penalties or a lien on your interest, which can dilute or effectively forfeit it.
Ask directly, in writing, whether the specific program you are considering is assessable, whether it is turnkey or fixed-price, what happens if costs exceed the AFE, and what the consequences of non-payment are. The answer is in the offering and operating documents.
Every well must eventually be plugged and its site restored. That cost falls on the working interest, it arrives at the end of the well's life when revenue is at its lowest, and it can exceed the well's remaining value — meaning your last transaction in an investment may be an expense rather than a payment. Plugging costs vary widely by depth, condition, and state requirements, and regulatory standards have generally been tightening.
In addition, working-interest owners can carry exposure for surface damage, spills and releases, produced-water and disposal issues, induced seismicity where applicable, contamination claims, and long-tail liability that can arise years after production ends. Environmental liability regimes can attach to owners as well as operators, and can be joint and several — meaning a claimant may pursue any owner for the whole amount.
Ask: what bonding is in place, who holds it, is it adequate to actual plugging costs, and what happens to the plugging obligation if the operator fails?
A dry hole, a completion that will not produce commercially, a mechanical failure during drilling that causes a hole to be abandoned, or a well that never covers its operating cost can consume the capital allocated to it with no recovery. In a multi-well program the losses are spread across wells, which changes the shape of the outcome but does not remove it — wells in one field, one formation, and one operator's hands fail for correlated reasons.
A tax deduction reduces the after-tax cost of a loss. It does not convert a loss into a gain, and no deduction should be presented as a floor under your capital.
Revenue is volume × realised price, and price is outside anyone's control. Crude fell roughly 70% between mid-2014 and early 2016, fell sharply again in 2008, and the expiring WTI contract settled below zero on 20 April 2020. A sustained low-price period reduces distributions, can push a well below the price at which it is worth operating, and can cause wells to be shut in or abandoned early. Natural gas prices are separately volatile and regionally dislocated.
This is stronger than “not listed on an exchange.” There is no established secondary market for a private working interest, no market maker, no pricing service, and frequently no buyer at any price.
Transfers are additionally restricted: the operating and subscription agreements typically require the consent of the sponsor or operator, may impose rights of first refusal, and may prohibit transfers that would breach securities-law conditions or the program's ownership limits. Interests carry restrictive legends. Assume you hold to the end of the wells' life, that you cannot rebalance, and that you cannot raise cash from this position in an emergency. Any valuation you are shown is an estimate, not a quotable price.
You do not control the wells. The operator makes drilling, completion, workover, shut-in, and abandonment decisions, keeps the accounts, calculates your share, and pays you. Your outcome depends on their competence, their record-keeping, and their honesty.
If the operator becomes insolvent, revenue held on your behalf may be caught up in a bankruptcy, distributions can stop for an extended period, plugging obligations may fall back on working-interest owners, and finding a successor operator willing to take on marginal wells can be slow or impossible. Replacing an operator generally requires a vote under the operating agreement and cooperation you may not get.
You have no role in day-to-day management and limited voting rights. The sponsor may sponsor multiple programs at once, may hold interests in the same leases or wells, may be affiliated with the operator or with service providers, and must allocate costs, opportunities, and attention between programs. These relationships are conflicts of interest by definition. Read the conflicts section of the offering documents, and ask how costs are allocated between programs and who decides.
Wells fail for reasons that have nothing to do with geology or prices: casing collapse or corrosion, cement failure, tubing and rod parting, pump failure, stuck pipe or lost tools during drilling, sand and paraffin problems, water encroachment that kills a producing zone, and blowouts or well-control incidents. Some failures are repairable at a cost billed to you; some end the well permanently.
Ownership of oil and gas rights is often complex and imperfectly recorded. A break in the chain of title, an unreleased prior lease, an unlocated heir, a boundary or acreage discrepancy, or a lease that expires because a continuous-operations or shut-in requirement was not met can reduce or eliminate the interest you thought you bought. Title problems also hold revenue in suspense for months, and curative work is billed to the interest. Ask whether a title opinion has been obtained and by whom, and whether leases are recorded and in force.
Production has value only if it can reach a buyer. Pipeline or gathering capacity, compression, trucking availability, disposal capacity, and purchaser willingness all constrain sales — a completed well with no route to market earns nothing. Even when it sells, you receive a differential to the benchmark price for location and quality, and that discount widens when regional takeaway is tight. The headline WTI price is not the price you are paid.
Every well declines from its initial rate over its life. Meanwhile lease operating expense — labour, power, chemicals, water disposal, insurance, and compliance — is largely fixed per well and tends to rise. Falling revenue against rising fixed cost defines the well's economic limit: the point at which it is shut in and plugged regardless of remaining oil in place. Ask for the estimated LOE per well and the price at which the wells stop covering their costs.
A program is typically one field, one or two target formations, one operator, and one or two purchasers. Those are single points of failure, and they mean a program can go to zero while the price of oil rises. This is the structural difference between a private program and diversified public energy exposure. More on concentration →
Unless an independent petroleum engineer has issued a reserve report prepared to SEC or SPE standards — and you have read it — there is no third-party valuation of what you are buying. Estimates of reserves, recovery, and well life prepared by a sponsor or operator are internal estimates. “Proven reserves” is a defined term; nearby wells producing oil is offset production history, which is a different and weaker statement. Ask which one you are being shown.
Permitting, spacing, disposal, emissions, bonding, and setback rules change at federal, state, and local level, and can raise costs, delay or block drilling, or shorten well life. Rules governing produced-water disposal and plugging-bond adequacy have been tightening in a number of jurisdictions. Regulatory outcomes are political and cannot be forecast.
Tax treatment is a central reason many investors participate, and it is not fixed. Correcting a claim previously made on this page: oil and gas tax provisions have not been static. This site elsewhere describes 2025 legislation as having changed the landscape — which is itself evidence that the rules move. They have been amended repeatedly over the decades, in both directions, and can be amended again with or without transition relief.
Additional tax risks: deductions may be examined and disallowed on audit; the at-risk rules (§465) and basis limitations can restrict the loss you may claim; percentage depletion is limited by the small-producer, net-income, and 65%-of-taxable-income caps and is not available to everyone; alternative minimum tax and state treatment may differ from federal; income is sourced to the state where the wells are, which can create nonresident filing obligations; and K-1s from drilling programs are routinely issued late — plan on filing an extension. Consult your own CPA. Tax discussion last reviewed July 2026.
Rig availability, service-crew scheduling, permitting queues, frozen or muddy access roads, power outages, and severe weather all delay drilling, completion, and first sales. Delay is not merely an inconvenience: it postpones revenue, can shift a deduction into a different tax year than expected, and increases the chance that the price environment at first production differs from the one at subscription.
No oil investment can guarantee returns. Any promoter who does is likely fraudulent.
“Invest today or lose the opportunity” tactics are a red flag. Legitimate deals allow time for due diligence.
Operators who cannot show production history from prior wells or provide references should be avoided.
Published yield ranges for unfunded drilling programs are assumptions presented as data. Ask what they assume about price, volume, and cost — then change those assumptions yourself.
If nobody will tell you plainly whether the interest is assessable and whether your liability is limited, treat that as the answer.
A deduction reduces the cost of an investment; it is not a return on one. A deal that only works because of its tax treatment is a bad deal with good tax treatment.
Measures intended to reduce risk are described in each program's offering documents. Where they are described, the limits should be described with them:
Request the offering documents, geological basis, AFE, and operator background. Have your own CPA and attorney review everything — including the liability and assessability provisions — before investing.
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