Optimizing the Recovery Rate of an Unconditional Reservoir by Applying Hydraulic Fracturing: Simulation Approach

Abstract

In recent years, the global demand for energy has risen sharply, encouraging oil and gas companies to shift their focus toward unconventional hydrocarbon resources. With the rapid growth of the petroleum industry and advancements in technology, new extraction methods are replacing traditional approaches. Unconventional reservoirs represent a highly promising source of energy; however, their extremely low permeability restricts natural hydrocarbon flow, making commercial production challenging. To overcome this limitation, stimulation techniques are required, and among them, hydraulic fracturing has become the most widely used method. Hydraulic fracturing plays a vital role in enhancing the production of tight oil and gas by creating fractures and ensuring fluid movement toward the wellbore. During this process, fracturing fluids and proppants are injected into the formation. Proppants are small solid particles that prevent the induced fractures from closing under formation stresses. The success of a fracturing treatment largely depends on the correct selection of proppant type and size. Without proper proppant placement, fractures may close, resulting in reduced conductivity and poor production performance. This study focuses on evaluating the most suitable proppant type and size to improve permeability and maximize hydrocarbon recovery. Selecting an optimal proppant prior to field operations can help oil companies avoid excessive costs and operational inefficiencies. Several proppant types and size ranges were tested through simulations using FRACPROPT 2011. Based on the results, Brady Sand 12/20 was identified as the optimum choice due to its high conductivity and fracture-holding capability. The evaluation of production reveals that production exceeds one, confirming that hydraulic fracturing with the selected proppant significantly enhances well performance.