Performance Analysis of DN1750 and DN1800 Electric Submersible Pump for Production Optimization on the Oil Well

Agung Wahyudi Biantoro, Bambang Darmono, Hadi Pranoto

DOI: https://doi.org/10.37869/ijatec.v3i1.55

Article Viewers

Abstract viewed: 418 times
PDF viewed: 190 times

Abstract


Abstract. Electric Submersible Pump (ESP) is an artificial lift method to lift fluid from the reservoir to the surface with a certain production rate, the ability of the pump to lift a certain fluid to the surface is adjusted to the capacity of the well itself. Over time, the production of oil wells will experience a decrease in the rate of production which will cause a decrease in pump performance. In several oil wells, well maintenance activities have been carried out. Therefore, in this study, an analysis of pump performance and optimization of the ESP pump was carried out using the Nodal Variable Speed Drive analysis method. The goal is to determine the production capacity of the oil well and determine the pump speed as desired. Oil well performance analysis and optimization of the ESP pump were carried out by mathematical calculations with the optimization results obtained that the DN1750 pump was installed at a frequency of 50 Hz, 55 Hz, 60 Hz, 65 Hz, and 70 Hz. The Hz number does not cross the desired flow rate line (q optimum) or is outside the desired fluid flow rate range by the oil well so it can be interpreted that based on the observation of the optimization process, the condition of the DN1750 pump is not working optimally so that the oil production capacity is not optimal. The DN 1800 pump at a frequency of 55 Hz with a speed of 3300 rpm is in accordance with the production capabilities of oil wells so that the appropriate pump is obtained and is expected to work at optimum conditions. At a frequency of 55 Hz with a speed of 3300 rpm successfully cut the desired flow rate line (q optimum) from the observed oil well characteristics or is in the range of fluid flow rates desired by the oil well, which is 1936,698 Barrels Per Day (BPD) with wellbore pressure (PWF) 629 psi.


Keywords


Electric; submersible; pump oil; well; nodal; speed drive; pressure

Full Text:

PDF

References

Shahid, S., Dol, S. S., Hasan, A. Q., Kassem, O. M., Gadala, M. S., & Aris, M. S. (2021). A review on electrical submersible pump head losses and methods to analyze two-phase performance curve. WSEAS Transactions on Fluid Mechanics, 16(February), 1431. https://doi.org/10.37394/232013.2021.16.3.

Zhao, P., Wang, X., Liu, Y., Wu, M., & Yue, W. (2015). The design of oil well production engineering analysis system. Open Mechanical Engineering Journal, 9(1), 437442. https://doi.org/10.2174/1874155X01509010437.

Zhigarev, D. B., Lekomtsev, A. V., Gorlov, A. E., & Dengaev, A. V. (2021). Experimental studies of the efficiency of high-speed ESPs. E3S Web of Conferences, 266, 18. https://doi.org/10.1051/e3sconf/202126601023.

Chatzarakis, G. E. (2009). Nodal analysis optimization based on the use of virtual current sources: A powerful new pedagogical method. IEEE Transactions on Education, 52(1), 144150. https://doi.org/10.1109/TE.2008.921459.

TARYANA, N. (2014). Sonolog Test Sumur Minyak menggunakan Alat Total Well Management Echometer sebagai Well Analyzer Sumur di Pertamina EP Subang. ELKOMIKA: Jurnal Teknik Energi Elektrik, Teknik Telekomunikasi, & Teknik Elektronika, 2(2), 152. https://doi.org/10.26760/elkomika.v2i2.152.

Olufemi, A., Adesina, F. A. S., & Olugbenga, F. (2008). Predictive Tool for Bottom-Hole Pressure in Multiphase Flowing Wells. Petroleum & Coal, 50(3), 6773.

Feriyanto, D., Zakaria, S., Alva, S., Pranoto, H., Sudarma, A. F., & Wong, A. P. J. (2020). Closed-Horizontal Rotating Burner Development for Optimizing Plam Shell Charcoal (PSC) Production. International Journal of Advanced Technology in Mechanical, Mechatronics and Materials, 1(2), 3944. https://doi.org/10.37869/ijatec.v1i2.23

Shokri, A., Azdarpour, A., & Honarvar, B. (2017). Analysis of infl ow performance relationship and reservoir characteristics using Saphir software. Bioscience Biotechnology Research Communications, 10(1), 143150. https://doi.org/10.21786/bbrc/10.1/22.

Ahmed, S. A., Ahmed, K. K., Mohammed, L. A., & Zalam, A. G. (2019). Design project Project Title : Optimization of Oil and Gas Production Using Nodal Analysis Technique Prepared by : Sardam Akram Ahmed 14-00523. December. https://doi.org/10.13140/RG.2.2.29161.03680.

Ubanozie Julian, O., Stanley Toochukwu, E., Nnaemeka Princewill, O., Kevin Chinwuba, I., Anthony Chemazu, I., & Anthony, K. (2019). Mathematical Approach to Determination of Optimum Oil Production Rate in Oil Rim Reservoirs. Petroleum Science and Engineering, 3(2), 60. https://doi.org/10.11648/j.pse.20190302.14.

Fleshman, R. (1999). Artificial Lift for High-Volume Production Rod pumps bring oil to surface in many fields , but for better flow rates more than. 4963.

Julianto, C., Tulloh, H., Priambodo, A., Nugroho, M. R., & Kurniawan, H. (2020). Production Forecast Studies for Oil Well Performance Prediction and Field De-velopment Scenario Using Decline Curve Analysis in Multilayer Reservoirs: A Case Study of Field Z. December, 133139. https://doi.org/10.11594/nstp.2020.0520.

Nashawi, I. S., & Mir, M. I. (2016). Inflow performance relationships for layered solution-gas drive reservoir Inflow performance relationships for layered solution-gas drive reservoir Fuad H . Qasem , Adel Malallah , Ibrahim Sami Nashawi * and Muhammad Irfan Mir. January. https://doi.org/10.1504/IJPE.2016.084116.

Eghbali, S., & Gerami, S. (2013). Modification of vogels inflow performance relationship (IPR) for dual porosity model. Petroleum Science and Technology, 31(16), 16331646. https://doi.org/10.1080/10916466.2010.551232.

Zhang, J., Chen, X., Lv, B., & Feng, Y. (2016). Oil production rate and Recovery factor evaluation for Beierxi. Iceep, 306316. https://doi.org/10.2991/iceep-16.2016.53.


Refbacks

  • There are currently no refbacks.

Share This Article



Copyright (c) 2022 Agung Wahyudi Biantoro