Haynesville Leasing Is Heating Up Again: What I Heard at NAPE 2026

The Haynesville Shale has been through several cycles since it made headlines in 2008. It is one of the country's most prolific natural gas plays when operators are active and one of the quietest when prices fall.

Right now, we're back in a running hot phase. And NAPE 2026 made that very clear to anyone paying attention on the expo floor in Houston.

What's Driving the Renewed Leasing Push

Several market factors are supporting current Haynesville leasing activity:

LNG Export Contracts Are Getting Signed

Multiple LNG export projects along the Gulf Coast are operating, under construction, or in advanced permitting. Their operators and trading companies need long-term gas supply. The Haynesville has thick net pay, high BTU content, and proximity to Sabine Pass, Golden Pass, and Plaquemines LNG.

Long-term offtake contracts give producers a revenue floor that makes it feasible to commit capital to multi-well development programs. That capital flows directly into lease bonuses and royalty payments for East Texas landowners.

AI and Data Center Power Demand Is Real

I heard more discussion at NAPE 2026 about power demand from AI infrastructure than I expected. Large data centers consume substantial electricity, and new computing capacity adds demand to the power grid.

Texas, with its deregulated ERCOT market and significant gas-fired generation capacity, is a direct beneficiary. Higher power demand in Texas supports higher in-state gas prices, which in turn improves the economics of Haynesville wells supplying those power plants.

Gas Prices Have Firmed

This one is straightforward. The $2.00/MCF environment that made Haynesville drilling borderline uneconomic is behind us for now. Strip prices above $3.50 with upside potential give operators the confidence to run rigs and commit acreage capital.

What's Different About This Leasing Wave Compared to 2008

In 2008, the Haynesville leasing rush was frenzied and, in retrospect, ahead of the market. Companies leased everything in sight at high bonus rates, gas prices crashed, and a lot of those leases expired before a bit was turned.

The leasing push underway now is more measured and focused:

Operators know where the good rock is. Fifteen-plus years of production data, well logs, and completion analytics have refined the productive fairway considerably. Acreage that sits squarely in the high-productivity core is getting premium attention. Fringe acreage is being passed over.

Acquisition activity is taking place. At NAPE 2026, I saw signed packages change hands and term sheets in process. Operators with capital and LNG-linked revenue visibility were making deliberate decisions.

Royalty buyers are also active. Alongside leasing programs, companies are buying royalty interests and non-participating royalty interests (NPRIs) in the Haynesville. A royalty purchase is separate from a lease, though both can relate to the same property.

County-by-County Activity

The core of the current leasing push is concentrated in:

Harrison County, TX – Historically the heart of the Haynesville in Texas. Ongoing leasing and some Deep Bossier activity.

Panola County, TX – Active leasing programs from multiple operators. Proximity to infrastructure is a plus.

Shelby County, TX – Solid rock quality and increasing interest from operators running eastward programs.

Rusk County, TX – Activity picking up, particularly in the western portion where the Haynesville is well-established.

DeSoto and Red River Parishes, LA – The Louisiana side continues to see aggressive leasing, with some of the highest-performing wells in the play.

What Landowners Should Know Before Signing

If you're in one of these areas, the offer letter or landman visit may come before you've had time to think through your position. A few principles that matter right now:

Bonus rates are negotiable. The offered rate in a first call is rarely the ceiling. Knowing what adjacent acreage is leasing for gives you leverage.

Royalty fraction is your long-term interest. A 25% royalty on a productive Haynesville well is significantly more valuable over the life of that well than a higher upfront bonus with a 20% royalty. Don't trade long-term value for short-term cash unless you have a specific reason to.

Primary term and extension rights matter. Three- or five-year primary terms with options to extend are common. Review the lessee's obligations during that period and what happens if drilling does not occur.

I help landowners in Harrison, Panola, Rusk, Shelby, Nacogdoches, and surrounding counties evaluate lease offers, review terms, and negotiate positions that reflect the current market. If a lease is on your kitchen table right now, let's talk.

For a deeper look at the geology driving this activity, see my post on the Deep Bossier play and what it means for the broader East Texas fairway.