State of Art Fracturing Optimization Reduces Water Blockage in Unconventional Gas/Condensate Wells

Hydraulic fracturing (fracing) is the most effective technique for improving the productivity of gas condensate reservoirs. The water used during fracing creates the conductivity needed for production, however, it will also create water blockage in the path of gas flow. The pressure and flow rate behavior of a gas condensate reservoir is distinctly different from the behavior of a solution gas drive reservoir. The producing rate is not only affected by the pressure gradient but is also a more complex function of the actual value of the flowing bottomhole pressure. Initially, the additional pressure required during flowback is needed to produce the water used during fracturing. The reservoir energy to lift this water to the surface requires more pressure drop around the wellbore. Additionally, unnecessary water used during fracing operations incrementally increases the pressure drop near the wellbore. Increased pressure drop leads the formation to reach the dew point sooner and condensate banking start to build in the fracture system. Increased condensate banking leaves valuable liquid hydrocarbon in the reservoir. Water blockages reduce well productivity and speed up the condensate damage due to the high-pressure drop required. An innovative pattern recognition and machine learning technology was applied in real-time during fracture treatment to increase fracture complexity, improve fracture conductivity, increase diffusion surface area, and improve stage productivity index. This technology focuses on creating the most stimulated fracture surface area per volume of water injected, resulting in the same fracture surface area but with a large reduction in water injected. The reduction of the water leads to an improved well productivity index by minimizing water blockage around the wellbore. Increasing fracture surface area per volume of frac water injected has a positive impact on the post-frac productivity of treated wells by increasing condensate production rates with less drawdown compared with traditional frac designs. In addition, using the optimum water volume has reduced the cost of fracturing operations and the cost of water flow back disposal leading to significant increases in well Net Present Value (NPV). A field case will be presented with condensate performance. The use of real-time fracture optimization technology with the integration of rock and reservoir fluid properties leads to better well performance. Production benefits of increased condensate production result in no reserves being lost-in-place to condensate blockage. Added ESG benefits are reduced superfluous water use, pump time, and water disposal costs.