Expanding LNG export corridors along the Texas and Louisiana Gulf Coast have fundamentally decoupled core dry gas acreage economics from local spot volatility. We deliver AAPL-certified title examination, Net Royalty Acre (NRA) normalization, depth severance audits, and direct acquisitions for high-pressure gas units.
We abstract title, review division orders, and appraise minerals across prime Gulf Coast gas corridors.
DeSoto, Caddo, Red River, Bienville, Bossier, Sabine, and Webster Parishes (LA), alongside Panola, Harrison, Shelby, and San Augustine Counties (TX). High-rate horizontal wells with initial production often exceeding 25 MMCFD.
Webb, Dimmit, La Salle, and Zapata Counties. Overpressured dry gas and lean condensate zones providing vital feedgas for industrial Monterrey and Texas export terminals.
Reeves, Loving, Ward, Pecos, Culberson, and Eddy Counties. Prolific associated and non-associated gas in the Woodford, Barnett, Atoka, and Devonian formations.
Hughes, Pittsburg, Coal, Grady, and Canadian Counties. Prolific Woodford, Caney, and Mississippian dry gas reservoirs feeding eastern and Midwest markets.
Model your mineral acreage value based on Net Mineral Acres, lease royalty rate, basin benchmarks, and Henry Hub gas pricing.
| Tract Net Revenue Interest (NRI) | 0.01562500 (1.5625%) |
| Peak Monthly Well Production | 720,000 MCF |
| Peak Monthly Gross Royalty Check | $39,375 |
| 3-Year Estimated Cumulative Royalty | $567,000 |
| Market Value Range Benchmark ($/NRA) | $5,500 – $7,500 / NRA |
| Estimated Mineral Asset Value | $440,000 – $600,000 |
Includes tract division order analysis, 36-month decline forecast, post-production deduction audit rules, and recent basin transaction comps.
Deep gas development creates unique title and lease maintenance requirements that directly impact asset value.
Vertical and horizontal severance clauses prevent operators from holding deep gas horizons with shallow depleted oil production. We audit whether the base of the deepest producing perforation terminates rights to underlying Bossier or Woodford intervals.
Under Texas precedent (Heritage Resources and BlueStone Natural Resources), gas leases must contain express, unambiguous language to disallow gathering, treating, and compression deductions. We audit revenue stubs against lease terms.
When pipeline capacity is restricted, operators may shut in wells and tender shut-in royalties. Failure to pay strictly in accordance with lease timeframes and amounts can cause lease termination, reverting title to the unleased mineral owner.
For Haynesville acreage across Caddo, DeSoto, and Bossier Parishes, unexercised mineral servitudes prescribe after 10 years of non-use under La. R.S. 31:27. Drilling operations or unit production must be verified in parish records.
Submit your tract location, net acreage, or recent check stub details. We provide certified title runsheet abstracts, normalized NRA valuations, and principal acquisition offers.
A Net Royalty Acre standardizes mineral ownership to a 1/8th (12.5%) lease royalty benchmark. Formula: NRA = Net Mineral Acres × (Lease Royalty Rate / 0.125). If you own 40 Net Mineral Acres leased at a modern core 25% (1/4th) royalty, you own 80 Net Royalty Acres (40 × 2.0). All commercial institutional buyers price mineral assets on a $/NRA basis.
While liquefaction facilities have long-term offtake tolling agreements with European and Asian buyers, upstream wellhead netback prices are tied to regional pipeline gathering receipt points and Henry Hub NYMEX settlements. Acreage situated directly on interstate pipes connecting to LNG corridors (such as Gillis, Louisiana or Katy, Texas) commands premium pricing due to minimal basis differentials.
Under standard oil and gas lease terms in Texas and Oklahoma, operators are generally permitted to deduct proportionate post-production costs (dehydration, compression, treating, and gathering) unless the lease contains a specific, well-drafted "no-deductions" or "cost-free royalty" addendum. In Louisiana, Civil Code principles require operators to absorb costs required to make gas marketable unless negotiated otherwise.
For standard tracts with clear courthouse chains of title, title examination and runsheet assembly require 3 to 7 business days. Upon title sign-off, closing and wire disbursement can occur within 24 to 48 hours. If heirship gaps or unreleased deeds of trust exist, our in-house title strike team prepares the required curative affidavits.