Haynesville Investment Is Accelerating: Four Things Mineral Owners Should Watch

Investment activity in the Haynesville Shale has accelerated significantly in 2026. According to J.P. Morgan Securities analysts, mergers and acquisitions in the play have reached $7.8 billion year-to-date — surpassing the Permian Basin and signaling sustained, long-term confidence in natural gas demand from this region.¹ For royalty and mineral interest owners in northwest Louisiana and east Texas, that momentum is worth paying attention to — but it requires a clear-eyed look at what these changes actually mean for your interests.

What Is Happening in the Haynesville Right Now

Two transactions have reshaped the Haynesville landscape in 2026:

Williams Companies acquired Momentum Midstream for $5.5 billion, making Williams the largest gatherer of natural gas in the Haynesville Shale. Momentum brought approximately 1 million acres under lease and 4,000 miles of gathering and transmission pipelines to the deal. Williams CEO Chad Zamarin stated the acquisition “has established a premier Haynesville position that strengthens our ability to serve rapidly growing LNG, power and industrial demand along the Gulf Coast.”² Williams is now accelerating two major pipeline expansions — the Shelby Connector and the $1.5 billion Delta Access pipeline to the Gulf Coast — to meet that growing demand.²

Centalion Group (formerly Gunvor) acquired Silver Hill Energy Partners’ Haynesville assets for approximately $1.5 billion, giving the multinational commodities trader a $2 billion total position in the play. The assets include approximately 72,000 net acres and current net natural gas production of about 300 million cubic feet per day. Centalion cited the Haynesville’s position as “the pivot point between domestic and export markets” as central to its rationale.³

These deals are being driven by converging forces: Gulf Coast LNG exports are expected to double in the coming years, data center electricity demand is prompting utilities to convert and build natural gas-powered generation facilities,² and ongoing supply uncertainty in the Middle East has increased appetite for reliable domestic supply.^1,4

1. What Major Investment Does and Does Not Mean for Mineral Owners

Large-scale corporate investment in midstream infrastructure reflects confidence in long-term natural gas demand — and that is broadly positive context for mineral owners in the region. But it is worth being specific about what it does and does not mean for your interests.

What it does signal: that sophisticated, well-capitalized companies with long planning horizons see lasting demand for Haynesville gas. Williams and Centalion are not making short-term bets. Pipeline infrastructure built today is designed to move gas for decades.

What it does not automatically mean: that your royalties will increase immediately, that new wells will be drilled on your acreage in the near term, or that the value of your mineral interests has already changed. Midstream investment improves the economics and logistics of getting gas to market — but actual royalty income depends on operator activity on your specific property, the terms of your lease, and commodity prices at the time of production.

“It is encouraging news for the region, and over time better infrastructure should support more development,” said Luke Slabaugh, RL, Landman at Aliign Mineral Management. “But mineral owners should be cautious about reading corporate deal headlines as a direct statement about their individual royalty payments. The connection is indirect, and the details of your specific lease and operator relationship matter enormously.”

2. What Can Change After an Acquisition

When midstream or upstream companies change hands, the administrative effects on mineral owners can be significant — and are often overlooked until a payment problem surfaces. Here is what to watch for:

• Payor information changes. The company cutting your royalty check may change. If you have automated deposits or outdated contact information on file, disruptions can occur.
• Royalty statement formats change. New operators or midstream companies often use different accounting systems, which can result in different line-item descriptions, changed deduction categories, or unfamiliar well identifiers on your statements. A statement that looks different is not necessarily wrong — but it should be reviewed carefully.
• Owner records get transferred. When ownership of producing assets moves from one company to another, mineral owner records must be migrated between accounting systems. Records can be mis-keyed, ownership percentages can be entered incorrectly, and some accounts can be placed in suspense during the transition.
• Division orders may need to be updated. If a new operator takes over a well or unit, you may receive revised division orders requiring your signature before payments resume. Review these carefully before signing — the decimal interest shown should match your lease and prior division orders.
• Suspense accounts can accumulate. During system transitions, operators sometimes hold funds in suspense rather than distribute them. Those funds are still owed to you, but you may not receive them — or even know they exist — without actively reviewing your payment history.
• Communication channels shift. Land department contacts, revenue accounting personnel, and phone numbers change. Knowing who to contact at the new company, and how, matters when an issue arises.

“In our experience, ownership transitions are exactly the moments when mineral owners are most likely to encounter payment discrepancies — not necessarily through any bad intent, but because accounting systems change, records get transferred, and details can fall through the cracks,” said Rex Tamplin, CPA, founder of Aliign Mineral Management. “That is when having someone reviewing your statements and holding operators accountable makes the biggest practical difference.”

3. How Pipeline Expansion May Affect Mineral Owners

The Williams pipeline expansions — the Shelby Connector and the Delta Access pipeline to the Gulf Coast — are significant infrastructure investments that could affect mineral owners in several indirect ways. It is worth understanding the potential relationship, while recognizing that outcomes will vary depending on your location, your operator, and market conditions.

• Takeaway capacity and development economics. Adequate pipeline capacity to move gas from the wellhead to market is a prerequisite for profitable drilling. In areas where takeaway has been constrained, new pipelines can improve the economics of development and may support additional drilling activity over time.
• Basis differentials. The price your operator receives for natural gas — and by extension what flows into your royalty calculation — is often based on a regional hub price, not the national Henry Hub benchmark. Pipeline access and regional supply-demand dynamics affect that local price. Expanded infrastructure connecting the Haynesville to Gulf Coast markets may narrow the basis differential, potentially benefiting royalty calculations for some leases.
• Production timing. Infrastructure improvements do not translate immediately into new wells on your acreage. Operators make drilling decisions based on a range of factors including lease commitments, well economics, capital allocation, and rig availability. Pipeline expansion is one input — not a guarantee of accelerated development.
• Lease language matters. Whether and how basis differentials, gathering costs, or transportation deductions affect your royalty depends heavily on the specific language of your lease. Some leases protect royalty owners from these deductions; others do not.

4. What Rising Operating Costs May Mean for Your Royalty

The Dallas Federal Reserve’s Q3 2026 Energy Survey reported that cost pressures across the sector remain elevated above historical averages. Finding and development cost indexes, lease operating expense indexes, and supplier delivery times are all running above their series averages.⁴ That matters to mineral owners for a specific reason: post-production deductions.

Many leases permit operators to deduct certain costs — gathering, compression, processing, transportation — from the royalty owner’s share of revenue before calculating your payment. When operating costs rise, those deductions can increase, reducing what you actually receive even if production volume and commodity prices remain steady.

What to review:

• Your lease language. Does your lease specify a “gross proceeds” royalty, or does it permit post-production deductions? The answer significantly affects how rising costs flow through to your check.
• Your royalty statements. Are deductions clearly itemized? Are they consistent month to month? Have any new deduction categories appeared without explanation?
• Trends over time. A single month’s statement can be misleading. Reviewing several months of statements together can reveal patterns that a single review would miss.

On the price outlook side, the Dallas Fed survey reported that respondents’ consensus forecast for Henry Hub natural gas prices is $3.29 per MMBtu at year-end 2026, rising to an average of $4.28 per MMBtu five years from now.⁴ If that trajectory holds, royalty owners whose leases are well-structured stand to benefit meaningfully — making it all the more important to ensure your payments are being calculated correctly.

A Practical Checklist for Mineral Owners

Given the volume of change currently underway in the Haynesville, here are six specific items worth reviewing in your records and statements:

• Confirm your payor has not changed. Check recent statements against prior statements to verify the company name, address, and contact information are consistent — or that any changes have been clearly communicated to you.
• Verify your decimal interest. The ownership percentage shown on your current royalty statement and division orders should match your lease and deed. Even small rounding errors in decimal interest calculations can result in meaningful underpayment over time.
• Review any new or revised division orders. If you have received division orders following recent acquisitions or new well completions, compare the decimal interest shown to your prior documents before signing.
• Check for suspended funds. Contact your operator’s revenue accounting department to confirm whether any of your royalties are currently held in suspense, and if so, why.
• Review post-production deductions. Identify and compare deduction line items on your statements over the past six to twelve months. Look for new deduction types or significant changes in deduction amounts relative to production volume.
• Confirm all producing wells are reflected. Cross-reference your royalty statements against the Louisiana Department of Natural Resources or Texas Railroad Commission well records to verify that you are receiving royalties from all wells producing on your acreage or unit.

When Professional Assistance May Be Appropriate

If you have recently experienced a change in operator or payor, received new division orders you are uncertain about, noticed unexplained changes in your royalty statements, or simply have not had your payments independently reviewed in some time, a professional royalty review may be worth considering.

At Aliign Mineral Management, we work with royalty and mineral interest owners in northwest Louisiana and east Texas to review payment accuracy, verify ownership percentages, navigate division orders and suspense issues, and communicate directly with operators on our clients’ behalf. We do not guarantee specific outcomes — every situation is different — but we can help you identify discrepancies, ask the right questions, and ensure your interests are represented with the full weight of our accounting and landman expertise.

If any of the items on the checklist above raise questions, we are glad to help you work through them. Contact us to schedule a consultation.

Sources

1. Swaine, Liz. “Billion Dollar Changes in the Haynesville Shale, Energy Prices Expected to Stay High.” The Shreveport-Bossier City Advocate, October 16, 2026.
2. Williams Companies. Q2 2026 Earnings Presentation and related investor materials. Williams Companies, Inc., 2026. Also reported in: Swaine, Liz. “Williams Expands Northwest Louisiana Haynesville Shale as Data Centers Drive Demand.” The Shreveport-Bossier City Advocate, August 7, 2026.
3. Reuters. “Centalion Acquires Haynesville Natural Gas Assets from Silver Hill.” October 5, 2026. See also: Wallace, Joe. “Centalion, Fresh From Rebrand, Does Deal for U.S. Gas Fields.” The Wall Street Journal, October 5, 2026.
4. “Oil and Gas Activity Increases Despite Cost Pressures, Longer Supplier Delivery Times.” Dallas Fed Energy Survey, Q3 2026. Federal Reserve Bank of Dallas. dallasfed.org.
5. Oilfield Pulse. Enverus, September 18, 2026.

This article is intended for informational purposes only and does not constitute legal, financial, or accounting advice from Aliign Mineral Management.