Perpustakaan Digital ITB

Shale gas reservoirs have extremely low matrix permeability, requiring hydraulic fracturing to enable commercial production. However, poor fracturing design can reduce recovery and increase costs. This study aims to identify the most technically and economically optimal hydraulic fracturing design for the Lewis Shale by integrating reservoir simulation and economic evaluation. Using tNavigator, 150 scenarios were simulated based on variations in fracture stages (5–10), slurry rate (4,000–8,000 RB/day), and proppant concentration (10–50 %wt). A dual-permeability compositional model was applied, followed by economic assessment through Cost of Hydraulic Fracturing (CHF) and Net Present Value (NPV). The Simple Additive Weighting (SAW) method was used to select the best scenario. Scenario 11 (5 stages, 6,000 RB/day, 50% proppant) was identified as optimal, achieving a 22.17% recovery factor, highest NPV, and low CHF. Sensitivity analysis showed fracture permeability and porosity most affect gas recovery, while CHF is influenced by stage count, and NPV by gas price and production. This study lies in the development of an integrated optimization framework that combines reservoir simulation, economic evaluation, and multi-criteria decision-making (MCDM) in a structured and quantitative manner. This approach bridges the gap between technical and financial analysis and provides a scalable workflow applicable to other unconventional shale plays.