Vol. 36 No. 3 (2023): Revista ION
Articles

Technical-economic feasibility of implementation of a virtual sensor for production in wells of a field in Valle Medio del Magdalena in Colombia

Giovanni Vizcaya-Cedeño
ECOPETROL S.A.
Fernando Enrique Calvete González
Universidad Industrial de Santander
Giovanni Morales Medina
Universidad Industrial de Santander

Published 2023-12-12

Keywords

  • Virtual sensor,
  • Artificial neural network,
  • Production oil well,
  • Valle Medio del Magdalena,
  • Neuralnet package,
  • CAPEX
  • ...More
    Less

How to Cite

Vizcaya-Cedeño , G. ., Calvete González, F. E. ., & Morales Medina, G. (2023). Technical-economic feasibility of implementation of a virtual sensor for production in wells of a field in Valle Medio del Magdalena in Colombia. Revista ION, 36(3), 63–74. https://doi.org/10.18273/revion.v36n3-2023006

Abstract

Production professionals utilize well performance data from physical sensors to identify wells that require corrective maintenance to normalize production flows. The foregoing corresponds to support for the completion of corporate goals. However, the costs of physical sensors may restrict access to the required information in real-time. For this, virtual sensors (VS) arise as a low-cost alternative, which can predict production flows, based on data available from physical sensors and on procedures embedded in artificial neural networks (ANN). Herein, we expose a technical-economic feasibility analysis of the implementation of a production VS in wells with a Progressive Cavity (PCP) artificial lift system in a field in the Valle Medio del Magdalena of Colombia (VMM). For this, production data with 15 variables were used in the training and validation of different ANN architectures, according to the codes of the Neuralnet library of the free software environment R. Likewise, an evaluation of the economic impact derived from the implementation of the VS in wells of the VMM field is disclosed. According to the results, the ANN with an inner layer of 23 neurons and logistic activation functions reported the best prediction performance, with errors of ± 9,6 at 95 % confidence. On the other hand, the application of a VS based on the RNA for the wells with PCP of the VMM field would lead to a favorable economic benefit, with a net present value of $25,5 MMusd, considering a 10-year cash flow.

Downloads

Download data is not yet available.

References

  1. Doğan B, Erol D. The Future of Fossil and Alternative Fuels Used in Automotive Industry. En: 3rd International Symposium on Multidisciplinary Studies and Innovative Technologies (ISMSIT); 2019 October 11-13; Ankara, Turkey; IEEE; 2019. doi.org/10.1109/ISMSIT.2019.8932925
  2. Kreps BH. The Rising Costs of Fossil-Fuel Extraction: An Energy Crisis That Will Not Go Away. Am. J. Econ. Sociol. 2020;79(3):695–717. doi.org/10.1111/ajes.12336
  3. Kremieniewski M. Improving the Efficiency of Oil Recovery in Research and Development. Energies. 2022;15(2):4488. doi.org/10.3390/en15124488
  4. Soares FDV, Secchi AR, de Souza MBJr. Development of a nonlinear model predictive control for stabilization of a gas-lift oil well. Ind. Eng. Chem. Res. 2022;61(24):8411–8421. doi.org/10.1021/acs. iecr.1c04728
  5. García A, Almeida I, Singh G, Purwar S, Monteiro M, Carbone L, et al. An Implementation of On-line Well Virtual Metering of Oil Production. En: SPE Intelligent Energy Conference and Exhibition; 2010 March 23-25; Utrecht, The Netherlands; OnePetro; 2010. doi.org/10.2118/127520-ms
  6. Amin A. Evaluation of Commercially Available Virtual Flow Meters (VFMs). En: Offshore Technology Conference; 2015 May 4-7; Houston, Texas; OnePetro; 2015. doi.org/10.4043/25764-ms
  7. Bravo CE, Saputelli L, Rivas F, Pérez AG, Nickolaou M, Zangl G, et al. State of the Art of Artificial Intelligence and Predictive Analytics in the E&P Industry: A Technology Survey. SPE J. 2014;19(04):547–563. doi.org/10.2118/150314-pa
  8. Varyan R, Haug RK, Fonnes DG. Investigation on the Suitability of Virtual Flow Metering System as an Alternative to the Conventional Physical Flow Meter. En: SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition; 2015 October 20-22; Nusa Dua, Bali, Indonesia; OnePetro; 2015. doi.org/10.2118/176432-ms
  9. Varyan R. Cost Saving of Implementing Virtual Flow Metering at Various Fields and Engineering Phases - A Case Study. En: Offshore Technology Conference Asia; 2016 March 22-25; Kuala Lumpur, Malaysia; OnePetro; 2016. doi.org/10.4043/26637-ms
  10. Bikmukhametov T, Jäschke J. First principles and machine learning Virtual Flow Metering: A literature review. J. Pet. Sci. Eng. 2020;184:106487. doi.org/10.1016/j.petrol.2019.106487
  11. Hansen LS, Pedersen S, Durdevic P. MultiPhase Flow Metering in Offshore Oil and Gas Transportation Pipelines: Trends and Perspectives. Sensors. 2019;19(9):2184. doi.org/10.3390/s19092184
  12. Ursini F, Rossi R, Castelnuovo L, Perrone A, Bendari A, Pollero M. The Benefits of Virtual Meter Applications on Production Monitoring and Reservoir Management. En: SPE Reservoir Characterisation and Simulation Conference and Exhibition; 2019 September 17-19; Abu Dhabi, UAE; OnePetro; 2019. doi.org/10.2118/196654-ms
  13. George A. Predicting Oil Production Flow Rate Using Artificial Neural Networks - The Volve Field Case. En: SPE Nigeria Annual International Conference and Exhibition; 2021 August 2-4; Lagos, Nigeria; OnePetro; 2021. doi.org/10.2118/208258-MS
  14. Bello O, Ade-Jacob S, Yuan K. Development of Hybrid Intelligent System for Virtual Flow Metering in Production Wells. En: SPE Intelligent Energy Conference & Exhibition; 2014 April 1-3; Utrecht, The Netherlands; OnePetro; 2014. doi.org/10.2118/167880-MS
  15. Cai S, Toral H, Sinta D, Tajak M. Experience in field tuning and operation of a multiphase meter based on neural net characterization of flow conditions FLOMEKO. En: Proc. 12th Int. Conf. on Flow Measurement; 2004 September 14-17; Guilin, China; 2004.
  16. Mirzaei-Paiaman A, Salavati S. The Application of Artificial Neural Networks for the Prediction of Oil Production Flow Rate. Energ. Source Part A. 2010;34(19):1834-1843. doi.org/10.1080/15567036.2010.492386
  17. Al-Jasmi AK, Goel HK, Nasr H, Querales M, Rebeschini J, Villamizar MA, et al. ShortTerm Production Prediction in Real Time Using Intelligent Techniques. En: EAGE Annual Conference & Exhibition Incorporating SPE Europ; 2013 June 10-13; London, UK; OnePetro; 2013. doi.org/10.2118/164813-ms
  18. Ahmadi MA, Ebadi M, Shokrollahi A, Majidi SMJ. Evolving artificial neural network and imperialist competitive algorithm for prediction oil flow rate of the reservoir. Appl. Soft Comput. 2013;13(2):1085-1098. doi.org/10.1016/j.asoc. 2012.10.009
  19. Liu G, Wang L, Qu H, Shen H, Zhang X, Zhang S, et al. Artificial neural network approaches on composition–property relationships of jet fuels based on GC–MS. Fuel. 2007;86(16):2551-2559. doi.org/10.1016/j.fuel.2007.02.023
  20. Berry MJA, Linoff G. Data mining techniques. Nueva York: John Wiley & Sons; 1987.
  21. Swingler K. Applying Neural Networks, A Practical Guide. London: Press Limited Oval Road; 1996.
  22. Zhang Z. Neural Networks: further insights into error function, generalized weights and others. Ann Transl Med. 2016;4(16):300. doi.org/10.21037/atm.2016.05.37
  23. Thorn R, Johansen GA, Hjertarek BT. Threephase flow measurement in the petroleum industry. Meas. Sci. Technol. 2013;24:012003. doi.org/10.1088/0957-0233/24/1/012003
  24. Carvajal G, Maucec M, Cullick S. Intelligent digital oil and gas fields. Concepts, collaboration, and Right-Time Decisions. USA: Gulf Professional Publishing, Elsevier; 2018.
  25. Kluth ELE, Varnham MP, Clowes JR, Kutlik RL, Crawley CM, Heming RF. Advanced Sensor Infrastructure for Real Time Reservoir Monitoring. En: SPE European Petroleum Conference; 2000 October 24-25; Paris, France; OnePetro; 2000. doi.org/10.2118/65152-MS
  26. Kemp CE, Ravikumar AP, Brandt AR. Comparing Natural Gas Leakage Detection Technologies Using an Open-Source “Virtual Gas Field” Simulator. Environ. Sci. Technol. 2016;50(8):4546−4553. doi.org/10.1021/acs.est.5b06068
  27. Khan MY. Theory & Problems in Financial Management. Boston: McGraw Hill Higher Education; 1999.
  28. Carmalt SW. The Economics of Oil. A primer Including Geology, Energy, Economics, Politics. Switzerland: Springer; 2017.
  29. Brealey R, Myers S. Principles of Corporate Finance. New York: McGraw-Hill; 2000.
  30. Isasi P, Galvan I. Redes neuronales artificiales: enfoque práctico. Madrid: Pearson; 2004.
  31. Hastie T, Tibshirani R, Friedman J. The Elements of Statistical Learning. New York: Springer Inc; 2009.
  32. Sadri M, Shariatipour S, Hunt A, Ahmadinia M. Effect of systematic and random flow measurement errors on history matching: a case study on oil and wet gas reservoirs. J Petrol Explor Prod Technol 2019;9:2853–2862. doi.org/10.1007/s13202-019-0665-2
  33. Falcone G, Hewitt GF, Alimonti C, Harrison B. Multiphase Flow Metering: Current Trends and Future Developments. J. Pet. Technol. 2002;54(04):77–84. doi.org/10.2118/74689-jpt
  34. Andrade GMP, de Menezes DQF, Soares RM, Lemos TSM, Teixeira AF, Ribeiro LD, et al. Virtual flow metering of production flow rates of individual wells in oil and gas platforms through data reconciliation, J. Pet. Sci. Eng. 2022;208(Part E):109772. doi.org/10.1016/j.petrol.2021.109772
  35. Gevrey M, Dimopoulus I, Lek S. Review and comparison of methods to study to contribution of variables in artificial neural network models. Ecol. Modell. 2003;160(3):349-264. doi.org/10.1016/S0304-3800(02)00257-0
  36. Luíza da Costa N, Dias de Lima M, Barbosa R. Evaluation of feature selection methods based on artificial neural network weights. Expert Syst. Appl. 2021;168:114312. doi.org/10.1016/j.eswa.2020.114312
  37. Zuluaga-Álvarez W.J. Evaluación económica de la actualización del sistema de monitoreo remoto en los pozos con inyección de agua, bloques I y II, del campo Casabe (Tesis de maestría). Bucaramanga, Colombia: Universidad Industrial de Santander; 2020.