The Variable That's Separating Good Wells from Good Investments

MARKET PULSE
Infrastructure Is Quietly Becoming the Most Valuable Asset in U.S. Energy

For years, the shale story was dominated by one question: how fast can operators drill and grow production? That question is changing.

Today, some of the most important constraints in U.S. energy are no longer underground. They are above ground. Pipeline capacity, gas processing, export terminals, rail access, power availability, and water infrastructure are increasingly determining which basins can grow profitably and which ones cannot.

The Permian Basin remains the clearest example. According to the U.S. Energy Information Administration, the Permian is expected to continue leading U.S. crude production growth in 2026, but operators continue to highlight associated gas takeaway and midstream coordination as critical variables in development planning. At the same time, LNG export expansion along the Gulf Coast continues pulling additional natural gas demand toward export markets, tightening the relationship between upstream drilling activity and infrastructure availability.

This shift is becoming visible across multiple basins. In Appalachia, operators continue to face pipeline limitations and permitting hurdles as barriers to accelerated production growth despite abundant resource potential. In the Haynesville, drilling activity has increasingly responded not just to Henry Hub pricing, but also to the timing of LNG demand growth and Gulf Coast connectivity. Even in the DJ Basin, where infrastructure is more mature, operators continue emphasizing integrated development planning and flow assurance as part of capital allocation decisions.

The same dynamic is now emerging in the Uinta Basin. Recent operator activity and acquisitions have brought renewed attention to the basin's oil-weighted inventory and improving well performance. But infrastructure remains one of the defining variables in how quickly the basin can scale.

This matters because markets are beginning to reward durable, infrastructure-supported production growth rather than growth at any cost. For royalty owners and long-term energy investors, this creates an important distinction: strong rock alone is no longer enough. The most resilient assets are increasingly those supported by high-quality operators, disciplined development plans, and infrastructure systems capable of sustaining long-duration production growth.

If you’re curious how we evaluate which operators and basins make the cut for PetroPeak acquisitions, that’s worth a conversation. Book 20 minutes here

BASIN FOCUS 
The Uinta Basin's Growth Story Runs Through Infrastructure

For much of the last decade, the Uinta Basin remained outside the center of the U.S. shale conversation. While capital flooded into the Permian, Eagle Ford, and Appalachia, the Uinta was often viewed as a niche regional oil basin with transportation limitations and waxy crude challenges that restricted broader market participation. That perception is beginning to change.

Over the past two years, several major transactions and operational updates have repositioned the basin as one of the more closely watched emerging oil growth stories in the western United States. Larger, better-capitalized operators are consolidating acreage positions, drilling activity is increasing, and recent well performance continues to improve across several core development areas.

The operator list itself tells part of the story. Companies such as SM Energy, Northern Oil and Gas, Crescent Energy, FourPoint Energy, and Uinta Wax Operating now represent a more institutional-quality operator group than the basin historically carried. Much of that shift accelerated following SM Energy and Northern Oil & Gas's acquisition of XCL Resources' Uinta assets in 2024, alongside additional private equity-backed consolidation activity.

What has drawn that capital is not simply acreage scale, it is well economics! SM Energy recently reported that Uinta production averaged approximately 87% oil during Q2 2025, with several Douglas Creek long-lateral wells producing near 870 BOE/d initial rates at roughly 94% oil content. Those are highly competitive results, and a major reason larger operators continue increasing capital allocation toward the basin. SM Energy has stated that Uinta returns are now competing directly with portions of its Midland Basin inventory.

Still, the basin's growth story is not without constraints. Unlike the Permian, which benefits from one of the largest integrated pipeline and midstream systems in North America, the Uinta remains more dependent on rail, trucking, local refining demand, and limited transportation corridors. Future growth may depend as much on infrastructure expansion as on drilling performance, a dynamic that closely resembles earlier phases of other shale basins before large-scale infrastructure caught up.

For royalty investors, this is where operator quality becomes especially important. The basin is increasingly attracting experienced companies with deeper technical teams, stronger balance sheets, and long-term development planning capabilities. Those are the types of operators most capable of navigating infrastructure bottlenecks while continuing to improve drilling efficiency and well performance.

The result is a basin that may still be in the early stages of its broader growth cycle and one that PetroPeak is actively monitoring as part of our ongoing acquisition evaluation. If you know someone who doesn’t forward this newsletter. They can subscribe at PetropeakNewsletter.

ROYALTY SPOTLIGHT
Why Market Access Matters to Royalty Owners

When most investors evaluate an oil and gas asset, the first questions are usually straightforward: How much oil will the well produce? What is the price? Who is the operator? Those are important questions, but they are not the only questions that determine long-term royalty performance.

One of the most overlooked drivers of royalty value is market access. Every barrel of oil must move from the wellhead to a sales point through gathering systems, trucking networks, rail terminals, pipelines, or export infrastructure. The quality and reliability of those systems can directly influence realized pricing, operating efficiency, production timing, and ultimately royalty cash flow.

Two wells with similar production profiles can generate materially different royalty outcomes depending on transportation constraints, crude pricing differentials, and end-market access. Strong infrastructure supports more stable development activity and stronger realized pricing over time. Bottlenecks, by contrast, create operational delays, increased transportation costs, and regional pricing pressure.

This is one reason PetroPeak's underwriting process extends well beyond reviewing production forecasts or headline well results. When evaluating mineral and royalty acquisitions, PetroPeak analyzes:

• Operator quality and long-term development history
• Basin infrastructure and takeaway capacity
• Proximity to gathering systems and transportation corridors
• Regional refining and market access dynamics
• Drilling inventory depth and development pacing
• Offset activity and completion trends
• Commodity mix and pricing exposure
• Long-term sustainability of production growth

Just as importantly, PetroPeak prioritizes assets operated by experienced companies with the financial strength and technical capabilities to navigate changing market conditions. Larger, disciplined operators are typically better positioned to secure transportation access, optimize marketing arrangements, and continue development activity through commodity price cycles.

In royalty investing, great wells matter. But great wells connected to reliable infrastructure, operated by disciplined companies, often matter even more. If you’re an accredited investor interested in participating in the next acquisition, now is a good time to connect. Connect With Us

INVESTOR ADVANTAGE 
Why Basin Selection Matters More Than Ever

One of the most common misconceptions in energy investing is that all oil and gas exposure behaves the same way. In reality, the quality of the basin often determines the quality and durability of the investment.

Over the past decade, U.S. shale development has become increasingly concentrated in a smaller number of highly economic regions. Operators continue directing capital toward areas with the strongest rock quality, deepest drilling inventory, and most reliable infrastructure systems. That trend has only accelerated as public companies place greater emphasis on free cash flow, operational efficiency, and long-term inventory sustainability.

Strong basins tend to attract larger and better-capitalized operators, continued drilling activity across commodity cycles, infrastructure investment and expansion, mergers and consolidation activity, and long-duration inventory development. The result is often a more durable production profile and more reliable royalty cash flow over time.

This is why PetroPeak focuses heavily on basin selection as part of its acquisition strategy. Rather than pursuing speculative frontier development, PetroPeak prioritizes proven producing regions with established operator activity, existing infrastructure systems, and long-term drilling visibility. That approach currently includes exposure across the Permian Basin, DJ Basin, Eagle Ford, Haynesville, and increasingly the Uinta Basin.

Not every basin evolves into a long-term growth story. The basins that tend to outperform over time are usually the ones where geology, operator quality, infrastructure development, and capital discipline begin aligning simultaneously. That combination is what we look for in every acquisition we evaluate.

For investors, this reinforces an important principle: the goal is not simply to own producing minerals. The goal is to own producing minerals positioned within basins capable of sustaining economic development for many years into the future.

WHAT WE’RE WATCHING
Three themes shaping our deal evaluation right now.

LOOKING AHEAD 
The Next Phase of U.S. Energy Growth May Look Different Than the Last

After nearly two decades of shale expansion, the U.S. energy industry is entering a more selective phase of development. The early years of the shale revolution were defined by rapid production growth, acreage accumulation, and large-scale infrastructure construction. Today, many of the premier shale basins are far more mature, and operators are increasingly focused on maximizing returns, extending inventory life, and improving operational efficiency rather than pursuing production growth at any cost.

That shift is reshaping where capital flows across the industry. Investors and operators are paying closer attention to the basins capable of delivering not only strong well results, but also long-term sustainability through infrastructure access, disciplined development pacing, and durable economics. The Uinta Basin is becoming one of the more interesting examples of this transition in real time.

Across the broader U.S. energy landscape, infrastructure is becoming one of the defining strategic variables shaping future development. LNG export expansion along the Gulf Coast continues increasing natural gas demand pull. Power demand associated with AI-driven data center growth is creating new electricity infrastructure requirements. Midstream systems, pipeline capacity, rail access, and refining connectivity are all increasingly important components of long-term basin competitiveness.

For royalty investors, this evolution matters. Long-term value creation increasingly favors assets located in economically resilient basins with strong operators, established infrastructure systems, and visible future development activity. At PetroPeak, this is exactly the framework that guides our acquisition strategy — and the reason we are actively expanding the portfolio into the most strategically positioned energy regions in North America.

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