Abstract Reduction in hydraulic fracture conductivity due to increase in stress has been identified as a major factor in the loss of productivity for hydraulically fractured horizontal Marcellus shale wells. The increase in effective stress, due to reservoir pressure depletion, results in proppant crushing, embedment, and diagenesis leading to hydraulic fracture conductivity impairment. The proppant size, type and concentration influence both the initial fracture conductivity and the degree of its subsequent reduction. The interplay among effective stress, natural fractures, and proppant performance must be considered to maximize the gas recovery from the Marcellus shale. This study seeks to assess the influence of proppant type, size, and concentration on hydraulic fracture conductivity and the productivity of the Marcellus shale horizontal wells with multistage hydraulic fractures. The available data from a horizontal Marcellus Shale well in West Virginia and the nearby wells were collected and analyzed to determine the natural fracture distribution, petrophysical, and geomechanical properties of the Marcellus shale. The hydraulic fracture properties, including the impact of stress shadow, were estimated from the treatment design by employing a commercial fracturing software. The results of the analysis were then used to develop a reservoir model for the horizontal well. The relations between fracture conductivity and the closure stress based on the proppant size, type, concertation were developed and integrated into the reservoir model. The commercial fracturing software was then employed to evaluate the impact of proppant size, type and concertation on the hydraulic fracture conductivity. The reservoir model was then utilized to investigate the impact of proppant size, type and concentration on the productivity of the horizontal. Results indicated that larger size proppants, while had minimal impact on short-term gas recovery, sustained fracture conductivity over longer production periods leading to higher gas recovery. Ceramic-based proppants, such as Curable Resin Ceramic and High-Density Ceramic, significantly enhanced initial and long-term gas recovery because of their superior ability to maintain fracture integrity. Higher proppant concentrations (2.5–3 lb/ft2) positively influence recovery over time. Overall, optimal proppant selection, considering size, type, and concentration, can substantially improve gas recovery, economic viability, and longevity of Marcellus Shale horizontal wells, emphasizing the importance of tailored strategies aligned with formation conditions.
Menhem et al. (Tue,) studied this question.