Merichem Technologies announced that its ECOTREAT® pilot achieved sustained removal of more than 99 % of hydrogen sulfide (H₂S) from gas in the Delaware Basin, the western part of the Permian Basin. This result matters to energy executives because it demonstrates a waste‑free, aqueous‑phase solution that could simplify sour‑gas handling, lower corrosion risk, and cut both capital and operating expenses for producers and midstream operators. By converting H₂S entirely to thiosulfate in solution, the process avoids the solid residues that typically burden liquid‑redox or solid‑media treatments, offering a cleaner, more manageable pathway for treating increasingly sour gas streams in one of the world’s most prolific basins.
ECOTREAT Field Trial Demonstrates Waste‑Free H₂S Removal
The month‑long trial injected gas containing up to 2 % H₂S (more than 14,000 ppm) into a unit that was originally rated for a maximum feed of 10,000 ppm. Despite this overload, the system exceeded its name‑plate capacity of 2 lb of H₂S removal per day while maintaining >99 % removal efficiency. The proprietary catalytic process converts H₂S to thiosulfate in the aqueous phase, eliminating the solid waste typical of liquid redox or solid‑media treatments. Only potash, already present in feed water or produced water, is required as a reagent. The resulting aqueous effluent can be discharged to salt‑water disposal facilities or sent downhole with produced water, allowing direct treatment of H₂S in produced‑water streams without additional handling steps.
Trial Context and Operational Parameters
The test was conducted across multiple wells in the Delaware Basin, covering a wide range of H₂S concentrations up to 2 %. Objectives included confirming sustained removal, defining the operating window, assessing solution capacity, and evaluating equipment performance when gas was treated with produced water from the same wells. Results showed that, even when less‑than‑ideal produced water was used as a feed reagent, the system treated all sales gas successfully. The trial also verified that the aqueous effluent meets disposal criteria for salt‑water systems, confirming compliance with typical environmental regulations in the region.
Implications for Permian Gas Production
The Permian Basin produces roughly 21.2 billion cubic feet of natural gas per day, with an increasing share classified as sour gas due to deeper, gassier formations. Producers are therefore investing in infrastructure to capture and treat acid gas. Merichem’s waste‑free, aqueous‑phase technology could reduce capital and operating expenses associated with solid‑media handling, mitigate plugging and downstream corrosion, and simplify compliance with environmental regulations. By eliminating solid waste, the process also lessens disposal logistics and potential liability. The company indicated that the technology is moving from pilot to full‑scale commercial rollout, positioning it as a potentially lower‑cost, lower‑complexity option for the basin’s expanding sour‑gas portfolio.
Key Takeaways
- The ECOTREAT field trial removed >99 % of H₂S, exceeding the unit’s design feed of 10,000 ppm by processing up to 14,000 ppm.
- The aqueous catalytic process converts H₂S to thiosulfate, producing no solid waste and requiring only potash as a reagent.
- Trial results were achieved using produced water from the same wells, demonstrating feasibility for direct on‑site treatment in the Delaware Basin.
EnergyInsyte's Take
Merichem’s results suggest a potentially lower‑cost, lower‑complexity option for sour‑gas handling in the Permian, where H₂S concentrations are rising. Executives should monitor the commercial rollout timeline and verify that the aqueous effluent meets site‑specific disposal regulations before committing to larger deployments.
Source: Businesswire
