PRODUCTION OPTIMIZATION OF ARTIFICIAL LIFT METHODS USING ELECTRICAL SUBMERSIBLE PUMP IN INTEGRATED FIELD

• Main Author: SUGIHARTO (NIM : 22209060), AGUS
• Format: Theses
• Language: Indonesia
• Online Access: https://digilib.itb.ac.id/gdl/view/20828
• Institution: Institut Teknologi Bandung

Artificial Lift Methods using Electric Submersible Pump (ESP) is one of the artificial lifting techniques with submersible pumps that give additional power to the fluid reservoir to help lifting the fluid to the surface through the tubing to the separator for a total cumulative production based on capacity of ESP. ESP is centrifugal pumps with designed based on multilevel where all parts of the pumps and their motors submerged in the fluid column in the well. The pump is driven by an electric motor through a motor shaft (shaft) that rotate the pump, and will rotate blades (impeller) pumps. <br /> <br /> <br /> This thesis aims to select the type of ESP that operates in a relatively long time interval with a range of optimum production rate in accordance with a reservoir capacity that meets the requirements of ESP operation. The execution of this research is done on the field model is integrated with all components in the oil field production system. The integrated system is represented by the simulator Petrel (reservoir) which combined with Eclipse and PIPESIM Simulator (production wells and flowlines) using the interface FPT (Field Planning tools). Integrated model is used to determine the work time of ESP operation at optimum production rate. Determination of ESP with long operating time span possible in some scenarios, with 6 inch ID casing. <br /> <br /> <br /> Simulation results show that the naturally flowing oil that produced the greatest amount with a flow rate of 40% of the initial IPR that is equal to 1,194,000 STB. After the wells are not able to flow naturally proceed with the installation of ESP on the next scenario. ESP wells are operating at optimum production rate with the longest operating times were subside D400 on wells 1, which operated for 2869 days with production of 516,000 STB, DN800 subsided to the well 2 with a range of operating time during the 2534 production of 531 800 days by the number of STB, Reda D400 wells for 3 with a range of over 2869 hours operating time with production of 529,600 STB and Reda DN800 for 4 with a range of well over 2534 hours operating time with cumulative production 529 900 STB. Total cumulative production for all production scenarios is 3.3021 million STB, with a recovery factor of 11.53% of OOIP for 28,648,828 STB