Publications

In order to support the government's goal of achieving a 1 million barrels of oil per day (BOPD) increase in production by 2030 and in alignment with the company's vision, Hydraulic Fracturing (HF) stimulation is identified as a viable option and solution for production enhancement. HF is anticipated to enhance the flow capacity of tight reservoirs, facilitating the extraction of oil to the surface. The Gumai Upper Formation (GUF) possesses a sufficiently thick sand interval with a net pay of up to 9 m, and an average permeability ranging from 0.97 mD to 3.27 mD, coupled with an average reservoir pressure of 1543 psi. Geomechanical properties of rocks in the formation, including a Poisson Ratio ranging from 0.01 to 0.24 and a Young Modulus ranging from 1.07E+06 Psi to 1.85E+06 Psi, highlight the importance of optimizing HF parameters for seamless operational execution in accordance with pre-established assessments and engineering designs. Fracturing results using 20/40 Carbolite in several wells in the Tempino Structure, considering various scenarios such as total proppant, fluid type, pad ratio, fluid efficiency, and others, yielded average values for fracture permeability (251 D – 495 D), fracture width (0.1 in – 0.4 in), fracture half length (28m – 130 m), fracture conductivity dimensionless (1.5 – 15), and net pressure (509 psi – 1110 psi), etc. The implementation of fracturing encountered both operation and reservoir challenges. Operation challenges such as poor gel quality, non-functioning breaker, mismatched total proppant pumped, clogged silo flow, frac pump loss of prime, and others, led to screen out. Also, reservoir challenge as the targeting a reservoir in the oil-water transition zone. Field experiences yielded reference values for GUF fracturing parameters, characteristics of resulting fractures, and valuable lessons learned, contributing to success criteria for hydraulic fracturing from both technical operational and subsurface perspectives.