A conservatively-estimated, tax-advantaged horizontal oil well in one of the strongest oil trends in America — where nearby wells have produced hundreds of thousands of barrels and the biggest names in the business are spending billions.
The same oil sand made small, tired vertical wells for 50 years. Then the industry started drilling it sideways with modern completions — and the results are a step-change.
Instead of one vertical puncture, the well runs a mile or more through the oil sand — contacting vastly more rock per dollar.
Modern frac designs place far more proppant per foot in engineered stages — the single biggest driver of the production step-change.
The streamlined “monobore” design pioneered in this play holds well cost to roughly $5–7M — better economics per barrel.
Opening the well slowly protects the reservoir — industry literature credits it with roughly 25–30% more oil over the life of the well.
A single nearby field alone holds an estimated 100–120 million barrels originally in place — the old wells barely scratched it.
Enhanced oil recovery is proven in this reservoir — a documented flood more than doubled a project’s oil rate. Refracs cost ~15–25% of a new well.
You do not have to take our word for the rock. Look at who is spending billions drilling and buying in this exact trend — right around this prospect.
A ~$16-billion private oil family runs the biggest drilling program in this play — and takes no promote. They drill purely because they believe the rock.
The operator that drilled the closest new laterals (~6 mi) is now part of a ~$30-billion public company — which filed an emergency development package one township north in April 2026 and is asking the state for approval to drill more wells there.
The company that published this play’s type curve agreed to sell its basin assets for $1.175 billion (announced May 2026) to a private-equity-backed buyer. That is what institutions pay to be in this basin.
More than $10 billion of acquisitions have hit this basin trend since 2023. That is institutional conviction — not a promoter’s story.
Per 2025–26 state records, five different operators hold live spacing cases, horizontal-well filings, fresh permits, or newly drilled wells inside this prospect’s exact township. The neighborhood is moving now.
42–48° API light-sweet oil realizing ~95% of WTI — a quality credit, not a discount — priced ~100 miles from the Cushing hub.
State-metered oil production for the ring of modern horizontals around the section, current through April–May 2026. Well names and exact locations provided under confidentiality agreement.
The best nearby well has made over 300,000 barrels in 18 months and is still flowing 400+ barrels a day. Our whole mid-case is 360,000 — this neighbor nearly got there in a year and a half.
The closest producing horizontal has delivered ~314,000 barrels in under three years — and was still making ~146 barrels a day in April 2026.
The play pioneer’s flagship well, on production since 2019, has passed 336,000 barrels — nearly seven years of checks from one wellbore.
A mid-2025 completion one township south produced 160,000+ barrels in its first eleven reported months. The newest wells in this play are among its best.
A horizontal on our same range line has produced for more than eight years and is still flowing — living proof of the long, flat tail these wells settle into.
A single Marchand lease in this trend has produced over 1.5 million barrels from six wells — a picture of what full development of one unit can become.
And on the section itself: four legacy vertical oil wells are still producing inside this very section in 2026. This is not a bet on whether the rock holds oil — oil has flowed here for decades. The modern lateral simply unlocks the 85–90% a vertical hole could never reach.
From state regulatory dockets and well records, November 2025 through June 2026. This is what operators are doing around the section as of this month.
A ~$30B public company filed a full development package one township north in March 2026, then asked the state for an emergency order — the filing operators make when a rig is imminent. It is also seeking approval to add wells at its laterals closest to us.
Across 2025–26, operators have filed multi-unit horizontal cases, spacing orders, and increased-density applications on at least eight sections of this township — plus one fresh horizontal permit and one newly drilled well.
Roughly 600 oil-and-gas leases have reportedly been filed in the township directly south in the last 24 months, alongside a reported ~133,000-acre seismic shoot sweeping north toward this acreage.
The operator of a new active well one township south is reported to be moving its drilling program north into this township — with live spacing and pooling cases already on file along the way.
The enhanced-oil-recovery unit in this same sand ~6 miles away spudded a brand-new well — fresh capital going into the very reservoir’s “second life” that sits above our base case for free.
Every spacing order, lease, and rig around the section raises the cost of entry. Participating before the township’s first big horizontal is public is what buying at $1,000/acre — instead of the $4,300–8,300 producing comps — looks like.
Regulatory items are from state corporation-commission docket records (primary source). Lease-count, seismic, and rig-movement items are as reported by area mineral owners and are labeled “reported.”
Production, rates, and returns — drawn from state data, published type curves, and our own economic model at $70 oil, essentially today’s market price. No rally required: full-cycle breakeven is ~$49, and the well stays cash-positive down to roughly $15 oil.
State-metered production through April 2026 — and it is still flowing 400+ barrels/day
Our mid-case sits ON proven wells — not above them
Top completions open above 2,200 BOE/day
Among the modern wells surrounding this prospect, roughly half performed strongly, about a quarter were marginal, and about a quarter were weak. Sand quality is the deciding variable, and our diligence is aimed squarely at confirming the sand before capital is committed. Offset-well performance does not predict the result of this well.
A conventional sand — durable cash flow, not a shale cliff
Illustrative only — not a projection, offer, or tax advice. It shows the year-one deduction, not an expected result; a deduction reduces tax on income you have already earned and is not a return. Actual results depend on sand quality, costs, timing, and prices, and a well can lose money. Tax treatment depends on your situation — consult your CPA. Final working-interest terms are set in the operating agreement.
The Southern Oklahoma Hoxbar Oil Trend — producing horizontals, the nearest new offsets, and the prospect area.
Illustrative view. Exact prospect location and well identifiers are confidential and provided to qualified participants under a confidentiality agreement.
Not a startup. A real, multi-generational Oklahoma oil company that has survived five oil-price crashes.
Incorporated 47 years ago — and still actively operating today.
Made an independently-checkable gas-field discovery of roughly 35 billion cubic feet.
Won a $4.56 million fraud verdict against a major oil company — upheld on appeal. A rare third-party stamp on their books and integrity.
23 wells flowing right now. Independently-tracked lifetime production of 4.1 million barrels of oil plus 54 billion cubic feet of gas — roughly half a billion dollars of energy delivered.
A Marchand horizontal on the same trend the industry’s biggest names are buying into — offered without a promoter’s markup.
4M+ barrels of oil and 54 BCF of gas produced (independently tracked since 1990 — the true total since 1978 is larger), worth roughly $475–570 million at reasonable prices.
University-trained geologists and a certified professional landman; members of the leading petroleum-industry associations. The founder built it; his sons run it today.
Company-reported: operated 400+ wells, participated in 1,000+, with a >80% completion success rate — each individually checkable by permit number at the state corporation commission.
When a small operator prevails against a supermajor in federal court — as the plaintiff — that says something about how they keep their books.
Compare the terms to what the market actually charges.
| Term | This Deal | Market / Typical Promoted Deal |
|---|---|---|
| Acreage cost | $1,000 / net acre | $4,300–$8,300/acre paid for producing acreage nearby |
| Net revenue interest | 78% NRI | 72–75% typical of promoted investor deals |
| Promote / back-in | None — heads-up | Hidden carries and markups are the industry norm |
| First-year tax deduction | ~100% (IDC) | Same code section — but only as good as the deal behind it |
| Well cost basis | ~$7M planning number | Market formula suggests ~$6M — we carry the conservative figure |
Land is only ~8% of total project cost — nearly all of your dollars go into the well itself. You pay your share of the well and receive your matching share of the oil.
The strongest pitch is one that survives scrutiny. Here is what we are confirming before any capital is committed.
Not yet — the strong producers are 6–10 miles away, and this section sits on the trend’s sparsely-drilled northern edge. But the township is filling in fast: per 2025–26 state records, five different operators hold live spacing cases, horizontal filings, a fresh permit, or newly drilled wells inside it, and a ~$30B public company filed an emergency development package one township north. Our diligence still centers on the key offset well log that confirms the sand thickness before drilling.
The operator is a 47-year company, but a deep horizontal is a specialist’s job. We require the drilling and completion contractors to be named, experienced in this play, and contractually committed — and the operator to hold a working interest alongside participants — before funds are placed.
Sand quality dispersion (in this trend roughly half the modern wells are strong, a quarter marginal, a quarter lose money), operator execution, land title including possible restricted tribal minerals, saltwater-disposal costs, and oil price. Every one of these has a specific diligence item attached — log audit, title opinion, disposal plan, and underwriting at $70 oil (right at today’s market) with a ~$49 full-cycle breakeven and roughly $15 cash-operating breakeven beneath it.
Because it sits on top of what real neighboring wells have actually produced — roughly 305,000–336,000 barrels each on state-metered data, with the best still flowing — and well below the published 660,000-barrel two-mile type curve for this play. It is a mid-case anchored to real wells, not a best case.
Intangible drilling costs — roughly 78% of the well cost — are deductible in year one for working-interest participants, and the balance depreciates. For a top-bracket investor that cuts the effective cost of participating by roughly a third. A deduction reduces tax on income you have already earned — it is not a return on the investment, and it does not indicate the well will produce. Confirm treatment for your own situation with your CPA.
Three stacked levers: a two-mile lateral roughly doubles recoverable oil (best case ~900,000 barrels); additional pay zones sit in the same wellbore column; and enhanced oil recovery has a documented track record in this reservoir — a flood that more than doubled a project’s oil rate. None of these are in the base numbers.
Serious inquiries only. Complete the form and Kingdom Exploration will follow up with the confidential project package — economics, maps, well data, and participation terms.
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