Investigation of an Unexpected Flow Event for a Duvernay Artificial Lift System and Optimization for Future Installation

Abstract

Abstract This paper summarizes the work of a client project investigating an "unexpected flow phenomenon" observed for an operational downhole jet pump installed in a deep, high-pressure, light hydrocarbon-condensate well in the Duvernay region of Western Alberta. The jet pump appeared to allow the well to produce multiphase condensate, water, and Non-Condensable Gases (NCGs) without the injection of power fluid. Due to a lack of understanding of the cause of this phenomenon, the well production rate could not be predicted for future installations. The objective of this work was to understand the underlying mechanisms causing this flow occurrence, and subsequently use the findings to optimize the artificial lift pump without the use of the injection system. This study was structured into three tasks: creating a custom fluid model for the Duvernay well; importing the custom model into Computational Fluid Dynamics (CFD) simulations to model the flow through the jet pump; and verifying the accuracy of the simulations with a coupled wellbore analysis of the Duvernay system. The fluid model was created with an in-depth Pressure-Volume-Temperature (PVT) analysis using the chemical composition of the production fluid determined from field samples. The Duvernay fluid model consisted of density, viscosity, and specific heat relationships as a function of the local temperature and pressure. The fluid model was implemented into three-dimensional (3D) multiphase flow CFD simulations of the existing jet pump to characterize the flow. The results showed that the jet pump nozzle created a sharp pressure drop triggering the hydrocarbon mixture to flash from a supercritical fluid phase to a gas-liquid mixture resulting in a gas-lift effect that produced flow to surface. A one-dimensional (1D) radial wellbore analysis was conducted for a large range of production flow rates at the current field wellhead pressure to generate a well outflow curve. The discharge pressure of the CFD results was compared to the wellbore pressure at the pump depth to verify the results of the simulations. Using further CFD simulations, the pump was optimized by changing the nozzle and diffuser designs to reduce downstream turbulence and improve discharge pressure recovery. Lastly, a parametric study was conducted using CFD for multiple mass flow rates and nozzle diameters to create a semi–empirical model to predict production rates for any given pump size. This model was used for a second case study to test feasibility in future Montney region wells, in which optimal pump specifications were sized based on the region's downhole properties. The results of this case study showed that this new optimized pump has the capability to produce flow rates in wells that do not naturally produce condensate, with a predictive model having been developed to choose the ideal pump geometry specifications to maximize the outflow.