How to invest in oil & gas: the RESERVES framework

There are many ways to own oil & gas — public stocks and ETFs, royalty trusts, private funds, drilling partnerships, minerals and royalties — and the comparison guide ranks them by liquidity, risk, and tax treatment. This page is about the harder question: once a direct deal is in front of you, how do you decide? What follows is the discipline I apply on the operating side before drilling capital moves — written down as eight tests. Run them in order. Stopping early is a feature: each test exists to kill the deal before the next one can seduce you.

R — Rock: reservoir quality

Everything starts with geology, because no fee structure, sponsor pedigree, or tax deduction adds a barrel to the rock. Identify the basin, the target formation, and the specific producing intervals — then confirm the acreage sits inside the proven fairway of that play, not on its speculative fringe. In every basin there is a map of where the play works; promoters are skilled at acreage that looks adjacent to it.

What to check: third-party reserve engineering (not the sponsor's internal numbers); offset well results within a few miles, from public state records; where the acreage sits relative to the basin's core counties; and whether the claimed intervals are actually developed at commercial rates nearby. Red flag: a "geology section" that names a famous basin but no formation, interval, or offset wells — famous rock is not the same as their rock.

E — Experience: the sponsor

You are underwriting people as much as rock. A sponsor's incentive is to show you the highlight reel; your job is the full filmography. Ask for the results of every prior program — dollars raised, dollars distributed, wells drilled versus promised — and how investors fared in 2015–16 and 2020, when prices broke. An operator who communicated honestly through a bust is worth more than one who has only seen $80 oil.

What to check: complete program history; the operator's record with the state commission (violations, orphaned wells); how much of the sponsor's own cash — not carried interest — is in this deal; and reference calls with prior investors you find, not ones they supply. Red flag: a cold call. Quality allocation is not sold to strangers by phone.

S — Structure: the deal terms

This is where most retail oil & gas deals actually fail — not underground, but in the Use of Proceeds table. Trace your dollar: syndication and selling costs off the top, a turnkey drilling price marked up over the actual AFE, management fees, and a sponsor carry or back-in. Each layer can be defensible; the total load is what decides whether you can win. If 30 cents of every dollar never touches the wellhead, the wells must outperform by 40%+ just to get you back to even.

What to check: Use of Proceeds and sponsor-compensation tables side by side; turnkey price versus AFE; the general-to-limited partner conversion mechanics; and assessment clauses that can call more capital from you. The full anatomy is in the DPP guide. Red flag: a sponsor who won't show the AFE.

E — Economics: the well math

Now — and only now — model the wells. Take the sponsor's type curve and stress it: first-year decline of 25–50% for horizontal shale, well cost at the high end of the range, realistic LOE and severance taxes, and a price deck you choose, not theirs. My standing rule from the operating side: if the deal doesn't work at $50 oil or $2.50 gas, the deal doesn't work — anything above that is upside, not thesis.

What to check: breakeven price per barrel or mcf; payout period at your conservative deck; how returns change if wells come in 20% under the type curve; and NRI math — you are paid on net revenue interest, not the working-interest percentage on the cover page. Red flag: projections quoted only as "monthly income" with no decline curve shown.

R — Risk class: the interest type

Two investors can own the same well and hold utterly different risks. A working interest pays costs, carries liability, and earns the biggest share plus the biggest write-offs. A royalty or mineral interest takes revenue off the top with no cost obligation and no liability — smaller tax benefits, far fewer ways to be hurt. Fund and partnership units sit in between, with the sponsor's structure deciding what you really hold. Know which class you're being offered and whether that class — not the well — fits your situation.

What to check: general vs. limited partner status and the liability window; assessment exposure; distribution priority (who gets paid first when revenue disappoints); and whether the class you're buying matches the pitch's math. Red flag: "royalty-like income" language attached to what is legally a cost-bearing working interest.

V — Valuation: price vs. value

Every interest has a value independent of what anyone is asking for it: the discounted value of its future net cash flow, declining year by year. Build that number yourself before you look at the ask — this is where I've spent my career, and it is the single most skippable-looking, least skippable step in the framework. The royalty calculator does the arithmetic for income streams; producing-well deals get the same treatment with a decline curve and a discount rate you'd demand from any other illiquid asset (buyers in this market use 10–20%).

What to check: value at your discount rate versus the ask; the implied multiple of next-twelve-months income versus the 3–6× range real buyers pay; and what growth assumptions the price silently requires. Red flag: any valuation that counts the tax deduction as part of what you're "getting" — you're buying cash flow; the deduction just changes its tax character.

E — Exit: liquidity & horizon

Plan the divorce before the wedding. There is no meaningful public market for partnership units and only a thin, discount-heavy one for small royalty and mineral positions. The honest base case for a drilling partnership is holding to depletion — a decade or more of K-1s. If your life might need this capital back in five years, the deal fails here regardless of how good the rock is.

What to check: transfer restrictions in the partnership agreement; whether the sponsor has ever facilitated secondary sales, and at what discounts; for minerals, what comparable interests fetch at auction; and your own liquidity picture, honestly assessed. Red flag: "the sponsor will buy you out" promises that appear nowhere in the documents.

S — Shelter: the tax treatment

Last on purpose. The tax treatment of direct oil & gas is genuinely exceptional — IDC deductions of 65–80% of a drilling investment in year one, 15% percentage depletion on production, the §469 working-interest exception against active income — and it sits atop two other layers most investors forget: severance and ad valorem taxes that come off revenue before you're ever paid. Model all three layers to get a true after-tax return.

What to check: your GP/LP status and what it does to deduction usability; AMT exposure on large IDC amounts; the state tax stack where the wells sit; and — the test itself — whether the deal passed the first seven letters without the deduction. If the pitch leads with the write-off, the deal usually has nothing else to lead with. (High-bracket investors: the year-one deduction can offset a Roth conversion — the strategy our companion site covers in depth.)

Using the framework

In practice: score each letter pass/fail/flag, and let any two flags or one fail end the process. No single strength compensates — great rock doesn't cure a 30% load, and no tax benefit cures anything. The discipline feels slow exactly once; after that it's a 90-minute exercise with the offering memorandum and this site's guides open side by side. I'll be publishing worked examples — real deals I've scored, including ones I passed on and why — as the site grows; the basin analyses are the Rock test's reference shelf.