Thrasher #1

The surface location for the well is situated in Lafourche Parish, Louisiana, specifically targeting the western flank of the Leeville Dome in the Lake Raccourci area. The prospect spans a total of 848 acres (Maximum outline) situated within the highly productive Tex L trend. 

The primary objective lies at approximately ~13,500' TVDSS, zeroing in on the regional Textularia L producer interval—specifically the Leeville North Flank 95 and 96 sands, alongside the PCC/GG/HH sand series in the southwest block.

Thrasher is a clearly defined, fault-bounded trap. Modern seismic evaluation demonstrates powerful hydrocarbon indicators, showing a strong Class IIp / III AVO anomaly featuring a leading negative trough and a potent trailing peak composite amplitude.

Louisiana’s oil and gas sector experienced a significant rebound and regulatory overhaul in 2025, driven by surging natural gas production, major infrastructure milestones, and state tax reforms. State production rebounded as producers capitalized on growing demand for LNG, increased offshore lease sales, and state-level incentives. 

• Rig Count: Louisiana’s operating rig count has stabilized around 43 active drilling rigs. The split remains heavily weighted toward North Louisiana's Haynesville Shale (holding ~25 active units), alongside minor pullbacks in South Louisiana and a steady offshore count fluctuating up to 13 active rigs.​

• Permitting Upswing: Exploration has intensified, with Louisiana issuing 124 drilling permits in the first quarter of 2026 alone. This marks a steep 33.3% increase compared to the same period in 2025. ​

• Production and Pricing: Elevated commodity pricing continues to incentivize local drilling. The U.S. Energy Information Administration (EIA) estimates natural gas spot prices averaging $4.31/MMBtu for 2026 (a 15.1% increase over Q1 2025). This price strength is driving a projected production growth of 1.2 Bcf/d exclusively out of the Haynesville region.​

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• Key Operators: Majors such as Expand Energy (formerly Chesapeake), Apex Natural Gas, and Comstock Resources are leading the charge. They are concentrating their newest assets heavily across the Caddo, Bossier, and DeSoto parishes.​

• Port Arthur Louisiana Connector In-Service: Sempra Infrastructure officially placed its massive Port Arthur Pipeline Louisiana Connector into service. Completed ahead of schedule and under budget, the 72-mile, 42-inch pipeline originates with a crucial compressor facility in Beauregard Parish.​
• Direct LNG Supply Expansion: This newly activated connector adds 2.0 Bcf/d of transportation capacity. It acts as a direct feed gas pipeline supplying Phase 1 of the Port Arthur LNG export terminal.​
• Egress and Data Center Integration: The combination of newly expanded intrastate pipelines and interstate expansions has solidified Louisiana as the primary swing basin for global LNG export. Operators like Comstock are capitalizing on this by pairing gas production with newly announced, regional gas-fired off-grid power generation to support massive upcoming hyperscaler data centers.​

 Metric                                             Oil Volumes (MMBO)                                            Gas Volumes (BCF)

                  P90 (Low Case)                                     3.63 MMBO                                                                    7.26 BCF

                  P50 (Most Likely Case)                       6.43 MMBO                                                                   12.90 BCF

                  P10 (High Case)                                  10.86 MMBO                                                                   21.72 BCF

Before the widespread adoption of 3D seismic technology, exploratory drilling was guided by 2D data, which offered only a flat, cross-sectional view of the earth. Success rates for exploratory wells hovering around deep or complex structures were often below 20–30%.

• The 3D Seismic Advantage: By sending acoustic waves into the ground and recording the reflections, geophysicists can map the subsurface in three dimensions. This allows operators to visualize fault lines, salt domes, and stratigraphic traps with incredible clarity before a drill bit ever touches the ground.
• The Statistic: In modern deep-water and shelf drilling, the application of high-resolution 3D (and time-lapse 4D) seismic data has pushed exploratory success rates well above 50% to 70%, and development well success rates often exceed 90%.

At great depths, the time spent drilling equates directly to millions of dollars. Modern drilling technology has dramatically flattened the "learning curve" for deep wells.

• Modern Drill Bits and Rigs: The introduction of Polycrystalline Diamond Compact (PDC) drill bits, automated top drives, and high-efficiency mud pumps allows rigs to cut through hard rock formations much faster.
• The Statistic: The average time required to drill a deep well (e.g., 15,000+ feet) has decreased by 30% to 50% over the last two decades. What used to take 60 days can now frequently be completed in 30 to 40 days, significantly reducing the cost per foot drilled.

Drilling a vertical well into a deep reservoir requires hitting a target that may only be a few dozen feet wide, miles beneath the surface. For directional or horizontal wells branching off from these depths, the challenge is even greater.

• Measurement/Logging While Drilling (MWD/LWD): Modern drill strings are equipped with sensors near the bit that transmit real-time data (gamma ray, resistivity, porosity) back to the surface. Combined with 3D seismic models, engineers use "geosteering" to adjust the path of the well live.
• The Statistic: Modern geosteering allows operators to stay within the "pay zone" (the most productive layer of the oil reservoir) more than 90% to 95% of the time, compared to less than 60% using older, blind drilling methods. This precision maximizes the well's eventual oil production.

Deep drilling faces immense downhole pressures and temperatures (HPHT environments), which historically caused catastrophic equipment failures, stuck pipe incidents, or wellbore collapses.

• Managed Pressure Drilling (MPD): Modern automated fluid systems precisely control the pressure profile inside the wellbore during drilling. This prevents dangerous fluid influxes (kicks) and stops the wellbore walls from caving in.
• The Statistic: The percentage of total rig time lost to Non-Productive Time (NPT) due to mechanical failures or wellbore instability has dropped from historical highs of 20–25% down to under 5–8% on modern, technologically advanced operations.

By combining the structural "map" provided by 3D seismic with the real-time adjustments and ruggedness of modern drilling hardware, operators in regions like the Louisiana shelf can reliably target deep oil reserves that were previously considered too risky or economically unfeasible to drill.