The New Shale Equation

MARKET PULSE
The Production Thesis Is Evolving 

Over the last several newsletters, we have been following a trend that initially looked fairly straightforward. Oil and gas operators were demonstrating that they could maintain production while exercising remarkable capital discipline. As earnings season progressed, however, production did not simply hold up. Across a growing group of operators, expectations began moving higher without a proportional increase in capital.

Diamondback Energy's Q2 2026 results are the clearest single illustration of this trend. Diamondback averaged 525,000 barrels of oil per day and 1,018,000 BOE per day in Q2, surpassing the 1 million BOE per day milestone for the first time. The company raised its full-year 2026 oil production guidance to 522,000-plus barrels per day and total production to 1,000,000-plus BOE per day, while holding its capital budget unchanged at approximately $3.9 billion. Production growth without capital growth is not an accident. It is the output of efficiency compounding across a large, contiguous operating position. Wikipedia

The broader activity picture supports continued development momentum. As of the week ending July 2, 2026, the U.S. frac spread count rose by 5 to reach 205 active crews, according to Primary Vision data. The frac spread count measures hydraulic fracturing crews actively completing already-drilled wells and serves as a leading indicator of near-term production additions. Paired with a rig count that has reached its highest level since May 2025, the completion data suggests the industry is translating drilling activity into production at an accelerating pace. eia

The thesis we have been following is therefore becoming more specific. Capital discipline remains important, but the industry's production performance increasingly appears to be driven by something more fundamental:

Scale. Technology. Efficiency. Repeatability. More Production.

For royalty investors, there is another step in that progression. More repeatable development can also make future production easier to forecast. When operators repeatedly drill similar wells across large contiguous positions using established infrastructure and increasingly standardized development practices, both well performance and development timing become more predictable.

Production growth is the result showing up in earnings. Greater predictability may be the more important result for investors.

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 DJ Basin's Quiet Capital Migration

The Permian continues to receive most of the industry's attention, but sophisticated capital continues to find its way into another basin we have discussed frequently: the DJ.

JAPEX has been particularly aggressive. Earlier this year, the Japanese energy company completed its approximately $1.26 billion acquisition of Verdad Resources, establishing a significant operated position in the DJ Basin. The acquired assets included more than 1,000 producing wells, and JAPEX has outlined plans for more than 1,000 future development wells as it works toward approximately 50,000 BOE per day of production around 2030.

JAPEX subsequently announced another DJ-focused acquisition, agreeing to acquire Fundare Resources' Colorado and Wyoming assets. The significance extends beyond a single buyer entering the basin. Fundare's acreage complements JAPEX's existing Verdad position, giving the company an opportunity to create greater operating scale and pursue more efficient development across the combined acreage.

That rationale fits precisely with the broader trend emerging from earnings season. Consolidation creates acreage scale, but the real value is realized when that scale translates into better development. Contiguous acreage can support longer laterals and more efficient pad development. Existing infrastructure can be utilized across a larger production base. Drilling and completion practices can be standardized, operating knowledge can be transferred across a larger inventory, and capital can be concentrated where returns are strongest.

The DJ does not need to become the next Permian to create attractive investment opportunities. The basin already has established infrastructure, significant Niobrara and Codell inventory, high oil cuts in core areas, and decades of operating history. Development continues to evolve toward longer laterals and increasingly efficient large-scale programs, while operators including SM Energy, Occidental, Prairie Operating, and now JAPEX continue committing capital to the basin.

That is what makes the DJ particularly interesting from a mineral and royalty perspective. It does not always receive the headline valuation or investor attention of the Permian, yet development continues and sophisticated capital continues to enter the basin.

Sometimes the most interesting investment opportunities are not located where everyone else is looking.

The Uinta increasingly belongs in that same conversation. Both basins remain relatively underappreciated compared with the Permian, yet each contains high-quality operators, significant remaining inventory, and opportunities for technology and operating scale to improve development economics over time.

ROYALTY SPOTLIGHT
The Operator Can Change the Value of the Acre 

Two mineral interests can have similar geology, similar royalty burdens, and similar undeveloped inventory and still deserve very different valuations. One of the most important reasons is the operator responsible for converting that inventory into producing wells.

This earnings season is providing increasingly clear evidence of how much operator capability matters. Crescent Energy's integration of acquired assets is a useful example. The company has reported substantial improvements in expected acquisition synergies as it applies its operating practices across a larger asset base. Devon Energy completed its merger with Coterra Energy on May 7, 2026, creating a premier large-cap shale operator with a high-quality asset base anchored by a leading position in the economic core of the Delaware Basin. The combination is expected to unlock $1 billion in annual pre-tax synergies through technology-driven capital efficiency gains and optimized capital allocation across the combined acreage. SM Energy is working through a similar integration following the Civitas combination. In each case, the strategic objective extends well beyond eliminating duplicate corporate overhead. These companies are identifying opportunities to improve drilling, completions, production operations, infrastructure utilization, and capital allocation across the combined acreage. Yahoo FinanceDevonenergy

For a royalty owner, those improvements can directly influence asset value even though the mineral owner contributes none of the development capital. A better completion can increase recovery. A longer lateral can improve development efficiency. Better production optimization can increase output from existing wells. Contiguous acreage can make development easier to schedule, and existing infrastructure can reduce operational constraints.

The geology underneath the mineral interest has not changed. But the operator's ability to extract value from it has.

This is why basin-level analysis alone is insufficient when evaluating mineral opportunities. Identifying productive rock is important, but understanding who controls development, how that operator performs, and where the acreage competes within its portfolio can be just as important.

The same acre can have a different investment value in different hands.

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 
Certainty Has Value

Investing in minerals requires making decisions today about production that may not occur for several years. That makes uncertainty one of the most important variables in the underwriting process. Geology helps determine what can be developed, but the operator has an enormous influence over what actually gets developed, when that development occurs, and ultimately how those wells perform.

That distinction matters when evaluating future royalty cash flow. An experienced operator drilling repeatable wells across contiguous acreage with established infrastructure and a visible multi-year development program provides considerably more information than one with limited nearby activity, inconsistent results, or uncertain capital availability. Recent well results provide better analogs for forecasting future production. An established rig program provides greater visibility into timing. A large inventory of similar wells provides evidence about expected decline profiles and recoveries.

At PetroPeak, those factors are an integral part of our underwriting process. We evaluate recent well performance, development cadence, capital allocation, drilling inventory, lateral design, spacing, infrastructure, and the relative importance of the acreage within the operator's broader portfolio. The objective is not to eliminate uncertainty from oil and gas investing. It is to understand where that uncertainty exists and reduce the range of possible outcomes wherever reliable information allows.

Consider two otherwise similar mineral positions. One is controlled by an operator repeatedly drilling comparable wells nearby with established infrastructure and a visible development schedule. The other depends on future development from an operator with limited activity and uncertain timing. The acreage might look similar on a map, but the investments should not carry the same value or the same risk.

This is particularly important when underwriting undeveloped inventory. Future wells can create significant mineral value, but assigning that value requires more than identifying locations on a map. The probability and timing of development matter. So does the confidence we have in expected production once those wells are drilled.

As operator scale, technology, and repeatability improve, those variables become easier to forecast.

Scale. Technology. Efficiency. Repeatability. Predictability. That progression is why operator quality is inseparable from mineral value.

If you are an accredited investor and would like to understand how PetroPeak applies this framework to current acquisition opportunities, we welcome the conversation.

 [email protected] | petropeakinvest.com

WHAT WE’RE WATCHING
Operator Synergy Realization Across Recent Combinations
The wave of major shale consolidation that began accelerating in 2024 has now produced several large combined entities that are moving through their first or second full operating cycles post-close. Devon's integration of Coterra, SM Energy's absorption of Civitas, and Crescent Energy's continued build-out across multiple basins all represent tests of the same underlying thesis: that scale creates development advantages that translate into better economics for acreage owners. We are watching how quickly synergy targets materialize in actual per-well cost and production data, and whether the efficiency gains operators are describing in earnings calls are showing up in the field results that ultimately drive royalty income.

The Frac Spread Count as a Production Leading Indicator
The Primary Vision frac spread count reached 205 active crews as of early July 2026, a figure that tracks hydraulic fracturing completion activity across the major shale basins. As rig counts have risen and DUC inventories have been drawn down, the completion data has become an increasingly important forward signal for near-term production additions. We are watching whether the current frac spread level sustains or builds through the second half of 2026, and whether the production response from recently completed wells continues outperforming expectations in the way that Diamondback's Q2 results illustrated. The relationship between completion activity and production growth is one of the clearest real-time indicators available to royalty investors.

Technology Adoption and Its Effect on Well-Level Predictability
Several operators this earnings season have moved beyond describing technology as a strategic priority and are beginning to quantify its effects on specific well outcomes. Diamondback's commentary on stacked innovation across well construction, targeting, and stimulation, Devon's use of AI-assisted production optimization, and Permian Resources' continued progress on drilling and completion costs all point toward a broader shift in how the industry manages variability at the well level. We are watching whether these improvements are producing measurably tighter distributions of well performance across large drilling programs, which would directly support the predictability thesis and have meaningful implications for how future royalty inventory should be valued.

LOOKING AHEAD 

Earnings season still has meaningful disclosures ahead, and the next several weeks will continue filling in the picture of how operators intend to deploy capital through the remainder of 2026 and into 2027.

We are watching Devon Energy's first full quarterly report as a combined company following the Coterra merger. Their commentary on integration progress, synergy realization, and capital allocation across the Delaware Basin, Anadarko, and Marcellus positions will be one of the more important earnings data points of the season for operators with multi-basin scale. How quickly $1 billion in targeted synergies begins showing up in per-well economics and capital efficiency will tell us a great deal about how repeatable the benefits of consolidation actually are.

We are also tracking SM Energy's integration of the Civitas assets and the implications for DJ Basin development activity, Crescent Energy's continued execution across its Uinta and Eagle Ford positions, and Permian Resources' progress on cost efficiency following its recent operational improvements.

Beyond individual operators, the natural gas demand story continues developing in ways worth monitoring closely. Power agreements tied to AI infrastructure, LNG export capacity additions, and gas-fired generation commitments are increasingly showing up as forward capital signals rather than aspirational commentary. How that demand growth translates into wellhead pricing and development economics over the next 12 to 18 months will have direct implications for royalty owners across gas-weighted and dual-commodity basin positions.

The evidence this earnings season continues pointing in the same direction it has for several quarters. The industry's most disciplined operators are producing more, spending less per unit, and building platforms that make future development increasingly repeatable. For mineral investors, that trend is worth following carefully.

We continue evaluating acquisition opportunities across our target basins and welcome conversations with accredited investors exploring mineral royalties as a long-term income and diversification vehicle.

 [email protected] | petropeakinvest.com

Newsletter Subscribe