A Texas natural-gas development project with roughly 400 wells already producing and a ten-year horizontal-drilling runway. Existing cash flow, third-party proved reserves, and a real year-one tax deduction.
2.2x conservative (P70) 4.2x base case (P50) 5.8x optimistic (P30)
13% conservative 26% base case 36% optimistic
70 to 90% year-one deduction target against ordinary income. A one-time benefit, not a return.
7–10 year target window, with distributions beginning once production cash flow supports them.
70 / 30 LP / GP profit share on distributions and exit proceeds. Limited Partnership interest in working and mineral interests.
$50,000 per unit Reg D 506(c) · verified accredited investors only
Natural gas supplies roughly 42% of the fuel powering the US electric grid. EIA and Goldman Sachs project about 35 gigawatts of additional continuous power demand from AI data centers by 2030, which is the equivalent of roughly 40 million new households arriving on the grid at once.
Roughly 400 producing wells at about 1,400 BOE per day. Capital sits behind real production rather than an exploration result.
A $48MM proved-reserve base, verified in an independent PV-09 report by Lee Keeling & Associates in March 2026.
Around 106 horizontal wells planned over ten years at 7 to 14 per year, prioritizing proved undeveloped locations.
Intangible drilling cost deductions have offset ordinary income since 1913. Roughly 70% of the investment in year one.
The plan is to start with wells that already pay, then use that cash flow to drill more and grow the value ahead of a planned exit.
~400 producing wells · ~1,400 BOE per day · ~58,000 acres held · EBITDAX positive.
$48MM PV-09 reserve report from Lee Keeling & Associates, March 2026, providing asset backing and the borrowing base.
~106 horizontal wells at 7 to 14 per year, PUD-priority, across East Texas and the Gulf Coast.
The distinction that matters in energy investing is whether the capital sits in front of the drill bit or behind existing production. This one sits behind it.
Figures come from the fund's own underwriting across three cases, scaled from the $100,000 model. Distributions begin once production cash flow supports them, with residual exit proceeds at the end of the ten-year window.
Below the $50,000 minimum. Figures shown for reference.
Base case, per $100,000 invested.
A year-by-year distribution schedule is published for the base case only. The conservative and optimistic cases are modeled to the totals shown above.
Illustrative projections drawn from the sponsor's underwriting across three forecast cases. Not guarantees. Actual results depend on commodity prices, production and multiple risk factors, and capital is subject to loss. Year one shows no cash distribution by design: early gross profits are reinvested into the drilling program before distribution begins.
Intangible drilling costs cover wages, fuel, supplies and site prep with no salvage value, and they make up roughly 60 to 80% of the cost to drill a well. They have been deductible against ordinary income since 1913.
It is a one-time deduction against ordinary income in the year you invest, covering intangible drilling costs and depreciation.
It is not an annual investment return. It reduces taxes owed once. It is not yield and it does not compound.
It requires general-partner participation to deduct against ordinary income, which carries general-partner liability. Discuss this with your own tax and legal advisors before investing.
Illustrative for a sample married-filing-jointly investor. Every situation differs and this is not tax advice.
Capital sits behind existing production and a third-party-verified proved-reserve base rather than a single exploration result.
Existing production of roughly 1,400 BOE per day underpins the position.
A third-party PV-09 report provides asset backing and the reserve-based loan borrowing base.
The reserve-based loan is secured against proved reserves rather than spot price.
Working and mineral interests in real oil and gas property.
The operating team reports capital invested alongside partners.
Independent PV-09 by Lee Keeling & Associates, March 2026.
Completed with no material exceptions, as reported by the operator.
Reserve-based lender in place with covenants met, as reported by the operator.
Production and reserves tracked against the borrowing base.
Reg D 506(c), with third-party accreditation verification required.
Investor portal plus a live Quarterly Business Review over Zoom.
This is not a complete list. Capital is subject to loss and the offering documents contain the full risk factors.
MitigantExisting production and $48MM of proved reserves back the cash flow, and the reserve-based loan is sized to reserves rather than spot price.
MitigantA PUD-priority program staged at 7 to 14 wells per year over ten years, sitting on top of producing assets rather than replacing them.
MitigantThe ordinary-income deduction requires general-partner participation and the liability that comes with it. Disclosed up front, and worth weighing with your advisors.
MitigantA long-hold private position with no guaranteed secondary market. Commit only capital that can be locked up for the full window.
Founder · Expedition Equity
Dylan is responsible for investment strategy, underwriting oversight and capital allocation at Expedition Equity. His background covers building and operating multi-location businesses, evaluating real-asset and operating-company investments, and navigating private-market structures across several asset classes.
That experience informs a disciplined, risk-aware approach to which opportunities get brought to investors and which partnerships are worth making. An early career in healthcare shaped a process-driven, analytical approach to risk and decision-making.
For this offering, Expedition Equity is bringing the PetroVybe ONE project to its investors alongside PetroVybe Holdings LLC, a private American oil and gas development group operating an existing Southeast Texas production base.
A limited partnership interest carrying working and mineral interests in roughly 400 producing wells across about 58,000 acres in Southeast Texas, plus participation in a ten-year horizontal-drilling program across East Texas and the Gulf Coast.
Not in year one. The design reinvests early gross profits into the drilling program before distribution begins, and distributions follow quarterly once production cash flow supports them. Residual exit proceeds come at the end of the 7–10 year window. If you need income immediately, this is the wrong deal for that, and the calculator above shows the year-one zero rather than hiding it.
The spread is the information. It shows how dependent the optimistic case is on pricing, where breakeven sits against today's market, and how much equity is at risk in the conservative case. Even the conservative case models a 2.2x net exit MOIC. Don't anchor on the base case alone.
No. The target is roughly 70% of the invested amount in year one, and the actual figure depends on how and when the partnership deploys capital. The deduction also requires general-partner participation, which carries general-partner liability. Your own tax advisor should look at this before you invest.
The position is backed by wells already producing and by $48MM of proved reserves in an independent PV-09 report. The reserve-based loan is sized against those reserves rather than spot price, which is what keeps a price move from triggering a forced sale.
A $150MM target equity raise alongside a $275MM reserve-based loan, with a 70/30 limited partner to general partner split of distributions and exit proceeds. The minimum investment is $50,000 per unit.
This is a Reg D 506(c) offering open to verified accredited investors only. Third-party accreditation verification is required as part of the subscription process, before funds are wired.
An existing, cash-flowing natural-gas asset with a third-party proved-reserve base and a ten-year drilling runway. A $50,000 minimum, open to verified accredited investors, with funds due December 17.
