CUE delivered detailed design and cost estimate for Eagle Ford client EOR pilot. The project tested huff and puff gas injection at 10,000 psi on two wells over 6 months, aiming to boost recovery from mature assets and extend field life.
Project Spotlight: Enhanced Oil Recovery (EOR) Injection Facility Design – Eagle Ford, Texas
CUE EPCM Partners was engaged by our client to develop the process design and cost estimate for a pilot Enhanced Oil Recovery (EOR) injection facility in the Eagle Ford basin. The project supported their initiative to test the “huff and puff” gas injection method—an EOR technique aimed at increasing hydrocarbon recovery by injecting high-pressure gas into a well, allowing it to soak, and then producing the enriched fluids. This method aimed to significantly boost recovery from mature wells and unlock additional value from existing assets.
Project Scope and Execution Strategy
The first phase of the project consisted of a three-month Detailed Engineering program (April–June), during which a Class 1 AFE cost estimate was developed. The estimate was supported by vendor quotes to ensure market-aligned pricing. The contracting strategy included a competitive bidding and vendor selection process, which helped mitigate schedule and cost risks.
The pilot was executed on two wells—Orton 1H and Orton 101H—using a two-week huff and puff injection cycle over a six-month period. The facility was designed to inject lean gas at 8–10 MMSCFD and 10,000 psig. Key systems included amine sweetening, TEG dehydration, mechanical refrigeration, and a four-stage reinjection compressor. All major systems were skid-mounted for ease of deployment and high mobility.
Strategic Benefits of EOR
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Increased Recovery Efficiency: The huff and puff method improved oil mobility and recovery in tight formations, boosting production from existing wells.
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Reduced Development Costs: By enhancing output from existing infrastructure, the project reduced the need for new drilling and minimized capital expenditures.
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Extended Field Life: The approach extended the economic lifespan of mature wells, maximizing asset value.
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Scalability: The modular design allowed for future field-wide deployment based on pilot results, minimizing ramp-up delays.
Project Costs
The total capital expenditure ranged between $5.3MM and $7.6MM, depending on rental versus purchase of major equipment. Due to its unique nature, the reinjection compressor was purchased, while other gas processing systems were sourced on a rental basis, optimizing cost for the pilot scope.
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