Production Optimization through Installation of Feasible Artificial Lift Technology: A Case Study

Abstract

This paper elaborates the selection of optimum artificial lift system (ALS) for a depleted well Beta TX-01. During the initial testing of well it was observed that the average gross production is 1300 BPD  or we can says it as 1180 BOPD and 120 BWPD, with 39.2 API gravity and a small amount of gas is produced along which is 0.396 MMSCF/D. The reservoir pressure drops as the well is being produced. Meanwhile the water cut was rapidly increasing day by day ultimately increasing the operating cost. Electrical submersible pump (ESP) is known for its high lifting capacities, it is a best fit for shallow wells having low gas content and no sand production as in Beta TX-01. The other ALS methods seems to be unfeasible for such a scenario. The results obtained from PROSPER simulation study indicates the ESP as the suitable ALS for low reservoir pressure that is below 1500 psig, it also recommends to change the tubing size from 2-7/8 inch to 3-1/5 inch as per as the SOPs for lifting higher volume of reservoir fluids. The work over job for the installation of ESP requires major changes in the completion assembly as well as at surface. The well is then tested at different operating frequencies to choose the optimum frequency keeping the running life of ESP in mind to avoid unexpected work overs in future. Hence, ESP increased the production output from the well making the well economical to produce. The well Beta TX-01 is producing 450 BOPD on ESP at an operating frequency of 54 Hertz with intake pressure of 1085 psig, discharge pressure of 2660 psig, and motor amperage of 38 Amps.