A Model for Refracturing Operations in Horizontal Wells Employing Diverting Agents

Abstract

This work presents a model for refracturing horizontal wells employing diverting agents. The goal is to quantitatively model the placement of diverting agents and fracture propagation, when re-stimulating the entire wellbore with multiple clusters of perforations accepting fluid. The model can be used to help estimate the outcome of refracturing and provide recommendations for refrac treatment design. Three types of perforations are identified before a refract operation: propped-depleted fractures, unpropped-depleted fractures and new perforations that have not been previously fractured. In the simulation, fractures are discretized into segments for leak off, pressure drop and width calculations. Fracture width and propagation are correlated to pressure by PKN fracture model. During refrac, the fluid distribution is calculated by a flow resistance model, and is shown to gradually divert from low pore-pressure zones to high pore-pressure zones by diverting agent stages. This diversion process is reflected in the increase of fracturing pressure for each successive stage in the refrac treatment. When bottom-hole pressure reaches a critical value, the propped-depleted fractures will widen. Two simple test scenarios are presented to show the fluid diversion process. A field refracturing treatment in the Haynesville Shale is simulated next. For the field case, a complete simulation workflow of the initial fracturing treatment, production history match and refracturing treatment was completed. The production history was simulated using a coupled geomechanical reservoir model to account for the pore pressure and stress change. The refracturing treatment simulation was performed using the model presented in this paper. The modeled bottom-hole pressure (BHP) during the refracturing treatment is compared with field data and matched the field BHP trend very well. This match can be expected to provide an estimate of the fluid diversion process. The estimated propped fracture length after refrac can be used for production prediction. Questions such as the amount of diverting agent to use, the desired diverting agent permeability as well as maximum diverting agent stages are explored based on the simulation results.

Review of Shale Oil and Gas Refracturing: Techniques and Field Applications

“…These temporary plugging agents are usually made of biodegradable materials such as polylactic acid (PLA), with particle sizes ranging from 8 to 200 mesh. After refracturing, they naturally degrade, restoring the gas production contribution of the sealed fractures, and the temporary plugging layer formed by the agents can withstand pressures up to 25.5 MPa [39].…”

“…Refracturing with expandable liners was conducted in one well in the Bone Spring formation of the Permian Basin. The well was drilled and fractured in 2012 [39]. Before the fracturing operation, the artificial lift equipment was removed, and a retrievable bridge plug was installed at the design depth to test the integrity of the ϕ139.7 mm casing.…”