Peer-reviewed veterinary case report
Dog or cat having trouble breathing after fracturing treatment?
By Yu X et al.·2026·Oil and Gas technology Research Institute, China·View original on Europe PMC →
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Original publication title: Simulation of Full-Area Propped Fracture Propagation and Productivity in Shale Gas Reservoirs.
Plain-English summary
This study looks at how to improve the process of extracting gas from shale rock, which is often done by injecting a special fluid to create fractures. The researchers found that using a thicker fluid helps move the tiny particles (called proppants) that keep the fractures open, but only up to a certain point. They also discovered that while smaller proppants can travel further, they might not help produce more gas. By carefully choosing the right mix of proppants and adjusting the fluid's thickness, they were able to improve gas production significantly. Overall, the study suggests that making these adjustments can lead to better results in gas extraction from shale.
Abstract
Low-viscosity slickwater is the dominant fracturing fluid for shale gas reservoir stimulation, characterized by superior capability in generating complex fracture networks yet inadequate proppant transport performance. This deficiency commonly leads to a limited propped fracture length and undesirable proppant placement profile. To address these challenges and enhance proppant placement quality as well as single-well gas productivity, a fully coupled numerical model integrating nonplanar 3D fracture propagation, proppant transport dynamics, and a black-oil model is developed using field geological and engineering parameters from actual horizontal wells. The impacts of key fracturing operation parameters on proppant transport behavior and well productivity are systematically investigated via numerical simulations. Results indicate that both proppant transport distance and gas production increase with rising injection rate, but the growth rate diminishes when the injection rate exceeds 16 m<sup>3</sup>/min. Similarly, increasing fracturing fluid viscosity improves proppant transport distance and gas production, while no further enhancement is observed once the viscosity surpasses 63 mPa·s. Smaller proppant particle size contributes to longer proppant transport distance but results in gradual degradation of well productivity. Under a constant total proppant volume, merely substituting a large fraction of small-sized proppants extends propped fracture length but fails to boost gas production. Optimally incorporating a moderate proportion of ultrafine proppants based on the original field scheme achieves superior proppant transport distance and productivity performance. Field tests validate that appropriately increasing fracturing fluid viscosity and ultrafine proppant dosage facilitates full-area proppant placement and contributes positively to gas production enhancement in shale gas reservoirs. The findings of this study provide significant guidance for optimizing injection rate design, fracturing fluid selection, and proppant type screening in shale gas hydraulic fracturing operations.
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Search related cases →Original publication on Europe PMC: https://europepmc.org/article/MED/41908401