Stacked-Pay Drilling Explained: Why Multiple Formations in One Wellbore Change the Risk Equation

What Most Investors Get Wrong About Drilling Risk

The first question most people ask when they look at oil and gas investing is a reasonable one: what happens if the well doesn't produce?

Fair concern. Geological risk is real, and we never pretend otherwise. But that question almost always comes from a specific mental model of how drilling works, and that model only tells half the story.

Most people picture a single-zone well. Pick a formation, drill to it, hope it produces. Binary outcome. One shot. Miss, and the capital you deployed has very little to fall back on.

That's not how we drill at BassEXP. Understanding the difference is the foundation of everything else on this page.

What “Stacked Pay” Actually Means

In the oil patch, “pay” refers to a hydrocarbon-bearing geological formation. A zone of rock that contains oil or gas in commercial quantities. “Stacked pay” simply means that multiple pay zones exist at different depths within the same drilling footprint, layered vertically like floors in a building.

When a wellbore is drilled through that column of rock, it passes through each formation in sequence. Instead of targeting one layer and moving on, the operator can evaluate every formation the bit encounters. Each layer is separated by non-productive rock, so each zone is geologically independent. One underperforming zone doesn't compromise the others.

The simplest way to think about it: a single-zone well gives you one shot on goal. A stacked-pay well gives you several, all from the same surface location, using the same drilling investment already in the ground.

Pay Zones vs. a Single Formation

This distinction changes what you're actually investing in.

A single-zone well bets everything on one geological outcome. If that formation runs tighter than expected, comes in shallower than the logs suggested, or just isn't commercial at current prices, your options shrink fast.

A stacked-pay well is different from the start. Each formation represents a separate opportunity. The decision to complete one zone, several zones, or come back later to evaluate more is driven by data, not pressure. That optionality is baked into the wellbore itself.

How Stacked Pay Restructures the Risk Equation

Moving from single-zone to stacked-pay thinking means moving from binary outcomes to probability-based thinking.

A single-zone well asks one question: will this formation produce commercially? The answer is yes or no.

A stacked-pay well asks a fundamentally different question: of the multiple viable formations in this wellbore, what are the cumulative odds that at least one, or more, produces at an economically meaningful level?

That's not a small distinction. It's the difference between placing a single bet and building a structured position with multiple independent paths to success.

We're not claiming stacked pay eliminates geological uncertainty. Nothing does. What it does is spread that uncertainty across several independent opportunities instead of concentrating it in one. That's a smarter way to structure risk, and it's the core reason our multi-well, multi-zone approach exists.

Why This Matters More Than Most Investors Realize

Plenty of investors who've looked at oil and gas before ran into the single-zone model, sometimes with disappointing results. A zone comes up short. The operator moves on. The investor's left wondering whether anyone really tried.

That experience isn't uncommon, and it's one reason we're direct about our methodology from day one.

At BassEXP, no well gets called non-commercial until every viable pay zone has been evaluated. That's not a marketing line. It's an operational standard we hold ourselves to on every project, because our capital is in the ground right next to yours.

Why Oklahoma Legacy Fields Are Built for This Strategy

Not every geological environment supports stacked-pay drilling equally. Oklahoma's conventional legacy fields are particularly well suited to this approach, and that's no accident. It's a primary reason we focus our work here.

Here is what makes Oklahoma legacy fields the right environment for this strategy:

• Multiple, repeatable pay zones: Oklahoma basins, including areas within the STACK and SCOOP plays, contain dense vertical stacking of productive formations developed over decades of conventional production history.
• Extensive historical data: Legacy fields carry detailed production records, well logs, and formation data accumulated over many years of prior development. That information reduces uncertainty at every stage of evaluation.
• Known formation behavior: When you drill in a proven conventional field, you are building on a documented geological record, not starting from scratch.
• Predictable zone characteristics: Operators who have worked these formations understand how each layer behaves, how it responds to completion techniques, and what production profiles to reasonably expect.
• Established infrastructure: Roads, equipment access, established vendor relationships, and local operational knowledge reduce execution risk and cost.

“Legacy” doesn't mean old or exhausted. It means data-rich, de-risked, and proven. These fields are where stacked-pay evaluation works best, because the information you need to make good decisions already exists.

BassEXP's three-generation presence in Oklahoma, combined with long-standing relationships with regional operators, geologists, wireline crews, and landowners, gives us access to formation knowledge that cannot be replicated by operators coming in from outside the region.

The Operational Reality: How We Evaluate Every Zone

The concept makes sense on paper. Seeing how it plays out in the field is another matter.

Not every formation a wellbore encounters gets completed. That wouldn't be disciplined. Completion decisions are made on data, formation by formation, using a process that includes:

1. Geological mapping before the drill bit ever turns: We evaluate the known formation history of the target area, study nearby well logs, and assess each prospective zone before the project begins.
2. Real-time log evaluation during drilling: As the well is drilled, mud loggers and wireline crews collect formation data that tells us what we are seeing in real time. That information drives completion decisions.
3. Individual zone assessment: Each formation is evaluated on its own merits for both technical viability and economic potential at current price assumptions.
4. A clear standard before moving on: We don't call a well non-commercial until every formation with economic potential has been fully considered. That's the standard, and it's what separates a disciplined operator from one that gives up too early.

What “Seeing It Through” Looks Like in the Field

On multiple BassEXP projects, we've re-entered wellbores, evaluated additional pay zones, completed deeper formations, and turned marginal early results into economically viable producers. That track record reflects a core operating principle: viable pay zones don't get abandoned because a first attempt came up short.

If you've worked with an operator who walked away after one miss, this distinction isn't abstract. It's exactly the difference you're looking for.

Recompletion Optionality: Future Value Already in the Ground

Zones not initially completed stay available for future recompletion as conditions change. That creates upside beyond the original completion, stretches the productive life of the asset, and supports a long-term ownership posture over a short-term transactional one. The optionality is built into the wellbore itself, at zero additional drilling cost.

Capital Efficiency: More Opportunity From Every Dollar Drilled

Drilling is the single biggest capital expense in any oil and gas project. Most of your investment goes here, and it's where the economics of the program are largely set.

Single-zone wells load the entire weight of that investment onto one geological outcome. Stacked-pay wells spread it across multiple independent opportunities, using the same wellbore, the same surface location, and the same installed infrastructure.

The practical advantages of this approach include:

• Reduced per-zone cost: Infrastructure, surface equipment, casing, and location preparation are shared across all zones within the wellbore.
• No additional drilling required to access multiple formations: The wellbore is already there. Evaluating and potentially completing additional zones does not require a new well.
• Improved capital deployment efficiency: More of the investment goes toward accessing productive geology rather than duplicating drilling costs across separate wells.
• Alignment with a lean operating model: At BassEXP, our low-overhead structure is designed to keep more capital in the ground. Stacked-pay strategy is a natural expression of that philosophy.

We put our own capital into every project alongside our investors. Capital efficiency isn't just a talking point for us. It's our own financial discipline applied directly to how we design and run every program.

How Stacked Pay Connects to Your IDC Deduction

The operational story matters. But for most of our investors, the financial structure around that strategy matters just as much. This is where intangible drilling costs come in.

IDCs are the expenses incurred during drilling that have no salvage value: wages, fuel, supplies, site preparation, ground clearing, and other costs tied to drilling and readying a well for production. They typically represent 60 to 80 percent of total drilling costs on a new well.

Under U.S. tax law, working interest investors can generally deduct 100 percent of IDCs in the year they're incurred, regardless of whether the well produces. This deduction has been on the books since 1913 and remains one of the most significant tax advantages available to private investors in any asset class.

Put it in dollar terms: $500,000 in IDCs at a 35 percent marginal tax rate produces roughly $175,000 in Year 1 tax savings. That's real money back in your pocket the first year, independent of production outcomes.

Why the Operational Strategy Matters to the IDC Story

IDC benefits apply whether or not a well produces. But stacked-pay drilling improves the odds of commercial production, which also improves the odds of generating long-term depletion benefits and monthly revenue alongside that Year 1 deduction.

A well with multiple viable zones isn't just a better operational investment. It's a more complete financial one.

Think of it this way: IDCs are the financial structure. Stacked pay is the operational strategy. When you understand both together, the picture clicks. You're not just buying a tax deduction. You're funding a disciplined, multi-zone exploration process with multiple independent paths to commercial production and long-term asset value.

For a complete breakdown of how intangible drilling costs work, including how they interact with depletion and working-interest ownership, visit our full IDC guide. You can also explore our tax benefits overview or use our investor tax calculator to see how the numbers apply to your specific situation.

What This Means for You as an Investor

Stacked-pay drilling doesn't eliminate geological risk. Nothing does, and anyone who tells you otherwise isn't being straight with you.

What it does is structure that risk more intelligently. Multiple independent formations inside a single wellbore create multiple separate chances at commercial success. Disciplined evaluation makes sure no viable zone gets overlooked. And a co-investment model keeps the operator's financial interests aligned with yours at every step.

Paired with IDC tax treatment, this approach creates an investment framework with real near-term financial benefits and multiple pathways to long-term production. That combination is worth understanding fully before you make any decision.

The best next step is getting informed. If you're ready to go deeper, we've built the resources to help.

Download our investor guide for a plain-English walkthrough of how working-interest investments work, what to expect from a BassEXP project, and how the tax advantages apply to investors like you.

If you would rather talk through your questions directly, Preston is available for a straightforward, no-pressure conversation. No sales pitch. Just honest answers from someone who has been doing this work for a long time and believes you deserve to understand it fully before you commit to anything.

Frequently Asked Questions

1. What is stacked-pay drilling, and how is it different from a conventional well?

Stacked-pay drilling means a single wellbore is drilled through multiple hydrocarbon-bearing formations (pay zones) stacked vertically in the same geological area. A conventional single-zone well targets one formation and lives or dies on that result. A stacked-pay well evaluates each zone the wellbore encounters as a separate, independent production opportunity. The difference is structural: stacked pay creates multiple paths to commercial success from one drilling investment instead of concentrating everything on one geological outcome.

2. Does stacked-pay drilling eliminate the risk of a dry well?

No, and we'd never suggest otherwise. Geological risk is part of oil and gas investing, and no drilling strategy removes it entirely. Stacked-pay drilling distributes that risk across multiple independent formations instead of concentrating it in one zone. If one formation underperforms, others in the same wellbore may still produce commercially. That's a smarter way to structure risk, but it's not a guarantee of production. We believe honest framing serves investors better than overclaiming.

3. Why does BassEXP focus on Oklahoma legacy fields specifically?

Oklahoma's conventional legacy fields offer something that frontier or newer plays cannot: extensive historical production data, known formation behavior, and repeatable vertical pay zones that have been documented over decades of prior development. That information reduces uncertainty at every stage of evaluation. Combined with BassEXP's three-generation presence in the region and long-standing relationships with Oklahoma operators, geologists, and field crews, our geographic focus gives us an informational and execution advantage that is difficult to replicate from the outside.

4. How do intangible drilling costs connect to a stacked-pay drilling program?

IDCs are the expenses incurred during drilling that carry no salvage value: wages, fuel, supplies, and site preparation. They typically represent 60 to 80 percent of total drilling costs, and U.S. tax law generally lets investors deduct 100 percent in the year they're incurred. Here's the connection: IDCs are the financial structure of the investment, while stacked pay is the operational strategy behind it. A well built around multiple pay zones improves the odds of commercial production, which also improves the odds of generating long-term depletion and revenue on top of the Year 1 IDC deduction. The two work together.

5. What happens if the first zone completed in a BassEXP well does not produce commercially?

We keep evaluating. BassEXP's standard is that no well gets called non-commercial until every formation with viable economic potential has been assessed. In practice, that means we use real-time log data during drilling, run individual zone assessments, and in some cases have re-entered wellbores to complete deeper formations rather than walking away early. Zones not completed initially also stay available for future recompletion, creating additional upside over the life of the asset. This commitment to thorough evaluation isn't incidental to how we operate. It's the foundation of it.