Abstract
Abstract In this work, a new mathematical model of a fractured well considering multiple factors (permeability stress sensitivity, multiple well interference, and multiple fracture interference) is established to simulate wellbore pressure performance and rate distribution in tight gas reservoirs. The new fracture discrete coupling mathematical model is established. The wellbore pressure solution can be obtained by pressure drop superposition and Stehfest numerical inversion. Seven flow stages are observed according to the characteristics of the pressure derivative curve. The influence of several significant parameters, including rate ratio, fracture half-length, well spacing, and stress sensitivity are discussed. Based on the developed model, we demonstrated a field case to verify model accuracy. This work provides new supplementary knowledge to improve pressure data interpretation for multi-well groups in tight gas reservoirs.
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