New Methods to Predict Inflow Performance of Multiply Fractured Horizontal Wells under Two-Phase Condition and Optimize Number of Fracture Stages

Abstract

A new method is presented to calculate the total inflow and associated productivity index (PI) under two-phase conditions by a sum of contributions from matrix and N multiple fractures using semi-analytical methods. Maximizing the net Present present value (NPV), the new inflow performance relationship (IPR) models can determine the optimal fracture stage number. Furthermore, the deliverable PI is used as an input to a network model to calculate the operating rate, taking into account the network constraints such as the node pressure, allowed flowrate, or choke in place. Through this analysis, one may determine that the horizontal well of interest may not flow at the maximum PI-it suggests that the network constraints dissipate the contribution from m stage(s) fractures. The number of fracture stages is then reset to (N-m), the IPR model is rerun, and an updated PI is imported into the network model. This process is iterated until the final optimization is achieved.This method can quickly optimize the number of fracture stages for horizontal wells under two-phase solution-gas conditions, assisting operating companies in planning field development.* Guoqing Han currently holds the faculty position at China University of Petroleum Beijing

Representing Hydraulic Fractures Using a Multilateral, Multisegment Well in Simulation Models

“…These include use of dual-porosity models, enhancement of the productivity index of the fractured wells (Zhang et al 2012), virtual well perforations to simulate the fractures (Bogachev et al 2011), and explicit fine-scale gridding. In full-field simulations, where an entire reservoir with complex geometry, multiple wells, and possibly faults is modeled, local grid refinement (LGR) is a popular methodology to represent hydraulic fractures.…”