Critical study of reservoir and hydraulic fracture parameters on cumulative shale gas production – a sensitivity analysis

Abstract Gas production from shale reservoirs is primarily influenced by reservoir matrix and induced fracture properties. This study conducts a detailed sensitivity analysis using the CMG-IMEX simulator to quantify the impact of key parameters on cumulative gas production. The results indicate that increasing matrix porosity from 0.07 to 0.15 enhances cumulative gas production by 30 %, as higher porosity allows for greater gas storage and improved flow connectivity. Similarly, Langmuir volume variation from 80 ft 3 –197 ft 3 results in a 50 % increase in cumulative gas production, while Langmuir pressure between 400 psi and 725 psi leads to a 40 % production improvement, emphasizing the role of adsorption capacity in gas recovery. Hydraulic fracture parameters also significantly impact production. Increasing the number of fractures from one to five optimizes gas production, resulting in a 25 % improvement, though further increases lead to fractured interference and diminishing returns. The optimal fracture width is found to be 0.035 ft, beyond which the pressure gradient weakens, reducing gas production efficiency. Additionally, fracture permeability shows a positive correlation with gas production up to 105 mD, after which multiphase flow effects cause a decline in output. These findings emphasize the necessity of optimizing both reservoir and hydraulic fracture parameters to maximize shale gas recovery efficiently. The study provides critical insights for designing cost-effective hydraulic fracturing operations, ensuring enhanced gas extraction from unconventional reservoirs.