Successful Implementation of a Microemulsion Surfactant in Solvent Systems Applied During Matrix Stimulation Treatments to Improve Condensate Banking Removal in Gas-Condensate Wells in Mexico

This paper presents the development and field application of an enhanced stimulation methodology for gas and condensate wells in the I Field. The approach was formulated after a detailed evaluation of current reservoir conditions, with the primary objective to address key factors that contribute to formation damage associated with retrograde condensation. The stimulation design, organic in nature, incorporated a next-generation surfactant additive engineered to promote fluid mobility through the formation of a thermodynamically stable microemulsion. Field implementation demonstrated the technique's potential to mobilize condensate banks in the near-wellbore (NWB) region and mitigate their detrimental impact on well deliverability. Initial matrix stimulation treatments in the field were predominantly acid-based and delivered favorable outcomes during the early stages of field development. These treatments removed NWB damage through acidizing and created new flow pathways, such as wormholes, that helped improve conductivity and reduced the pressure differential between the reservoir and the NWB region. However, progressive reservoir depletion over time led to reduced bottomhole pressure. In several instances, post-treatment pressure approached or fell below the dewpoint of the reservoir fluid, limiting the effectiveness of conventional acid-based techniques. To overcome this challenge, a customized solvent formulation was developed that lowers surface tension at the gas-condensate interface. The objective was to partially solubilize enriched liquid hydrocarbons around the wellbore and revaporize them into the gas phase. The solvent system, augmented with microemulsified surfactant additives, also reduced interfacial tension (IFT) between water and condensate, which helped improve the mobility of both phases. This contributed to significantly reduced fluid cleanup times and improved post-treatment flowback performance. The findings underscore the advantages of advanced surfactant additives in solvent- and acid-based stimulation systems. Fundamental benefits observed include: Effective mitigation of retrograde condensation-related damageStabilized post-treatment wellhead pressure, which suggests delayed condensate accumulationReduced post-treatment fluid recovery time Additional stimulation treatment results presented in this publication build upon prior work (de-Antunano-Munoz, Y., et al, 2025), in which stimulation chemistry and laboratory screening methodology for a microemulsion-enabled solvent system are detailed. Production results from these additional wells demonstrate the potential to perform successful stimulation interventions through customized chemistry and pump schedules designed for the specific requirements of the reservoir.