Modeling and simulation of fluid lift in an onshore gas producing well
The analysis of fluid lifting in gas wells is essential for evaluating the technical and economic viability of well operations. This process involves simulating production behavior, defining the timing for artificial lift implementation, and selecting suitable equipment. Effective analysis requires integrated knowledge of PVT fluid characterization and the simulation of pressure and temperature profiles from the reservoir to the surface. In this study, fluid lifting was investigated in an onshore gas-producing well in Brazil using two simulation tools: Multiflash, for PVT modeling, and ALFAsim, for 1D transient multiphase flow simulation. Fluid properties were modeled with the Peng-Robinson cubic equation of state with Peneloux volume translation. The generated PVT table was then used in ALFAsim to simulate flow and evaluate the well’s lifting behavior. Nodal analysis confirmed that the well initially flowed under natural lift, with gas, oil, and water production rates of 78.6 sMm³/d, 1.83 sm³/d, and 1.97 sm³/d, respectively, with less than 2% deviation from real data. However, under a prospective scenario with 60% water cut and 48 h of shut-in, liquid loading impaired natural flow recovery. Artificial lift via continuous gas lift (GLC), with an injection rate of 5,000 sm³/d, successfully restored production. These results demonstrate the importance of integrating fluid characterization and dynamic simulation to optimize production strategies, evaluate future operational risks, and design artificial lift solutions.