Article Sidebar

Download
PDF
Statistic
Read Counter : 75 Download : 43

Main Article Content

Abstract

This study proposed and evaluated the new hydrogen production design of the Gas Turbine - Steam Methane Reforming (GT-SMR) hybrid process. The superheated byproduct gas from the GT system is utilized as a combustion agent for the boiler of the SMR system, minimizing the required heat energy input for hydrogen production. The overall energy consumption and energy generation are calculated and simulated to determine the system's operational performance. Under no efficiency losses, the design is tested to understand how the significant input parameters such as temperature, pressure, and steam/methane ratio (S/C) affect the system's overall performance. From the data generated, the system's efficiency was directly proportional to the pressure and temperature while inversely proportional to the S/C values. However, in actual applications, the menthane conversion rate often fluctuated depending on the adjustments of these factors, regardless of their thermodynamic relationship with the SMR efficiency. With the addition of other energy waste information, a complete simulation showed the reversed effect of pressure. Although the temperature and S/C ratio improved the overall performance, the hybrid system efficiency reached its limits beyond certain values.

Keywords

Steam methane reforming Hydrogen production Flameless combustion Gas turbine

Article Details

How to Cite
Tran, M. H. ., & Hosseini, S. E. (2024). Design and thermodynamic analysis of a hybrid gas turbine-steam methane reforming system. Future Technology, 4(1), 1–11. Retrieved from https://fupubco.com/futech/article/view/227
Download Citation
Endnote/Zotero/Mendeley (RIS)
BibTeX
Bookmark and Share

References

  1. Hosseini, Seyed Ehsan, Hydrogen Diplomacy. Future Publishing LLC, 2024. DOI: https://doi.org/10.55670/fpll.book/1, ISBN: 979-8-9906790-0-9
  2. K. A. Lewinski, D. van der Vliet, and S. M. Luopa, “NSTF Advances for PEM Electrolysis - the Effect of Alloying on Activity of NSTF Electrolyzer Catalysts and Performance of NSTF Based PEM Electrolyzers,” ECS Trans, vol. 69, no. 17, pp. 893–917, Sep. 2015, doi: 10.1149/06917.0893ecst.
  3. T. Wang, X. Cao, and L. Jiao, “PEM water electrolysis for hydrogen production: fundamentals, advances, and prospects,” Carbon Neutrality, vol. 1, no. 1, p. 21, Dec. 2022, doi: 10.1007/s43979-022-00022-8.
  4. A. Z. Tomić, I. Pivac, and F. Barbir, “A review of testing procedures for proton exchange membrane electrolyzer degradation,” J Power Sources, vol. 557, p. 232569, Feb. 2023, doi: 10.1016/j.jpowsour.2022.232569.
  5. D. Elrhoul, M. Naveiro, and M. Romero Gómez, “Thermo-Economic Comparison between Three Different Electrolysis Technologies Powered by a Conventional Organic Rankine Cycle for the Green Hydrogen Production Onboard Liquefied Natural Gas Carriers,” J Mar Sci Eng, vol. 12, no. 8, p. 1287, Jul. 2024, doi: 10.3390/jmse12081287.
  6. L. Mingyi, Y. Bo, X. Jingming, and C. Jing, “Thermodynamic analysis of the efficiency of high-temperature steam electrolysis system for hydrogen production,” J Power Sources, vol. 177, no. 2, pp. 493–499, Mar. 2008, doi: 10.1016/j.jpowsour.2007.11.019.
  7. Q. Ma et al., “Electrochemical Performances of a Solid Oxide Electrolysis Short Stack Under Multiple Steady-State and Cycling Operating Conditions,” Inorganics (Basel), vol. 12, no. 11, p. 288, Nov. 2024, doi: 10.3390/inorganics12110288.
  8. Locke, Karyssa. "The urgency of hydrogen: environmental issues and the need for change." Future Sustainability 2.2 (2024): 46-58. https://doi.org/10.55670/fpll.fusus.2.2.5
  9. Chowdhury, MD Farhan Imtiaz, MD Fahim Sadat Bari, Muhaiminul Islam, Wasif Sadman Tanim, and Redoy Masum Meraz. "Unlocking the potential of green hydrogen for a sustainable energy future: a review of production methods and challenges." Future Energy (2024): 18-46. https://doi.org/10.55670/fpll.fuen.3.4.2
  10. Noor, Wahid Bin, and Tanvir Amin. “Towards sustainable energy: a comprehensive review on hydrogen integration in renewable energy systems”,Future Energy3(4), 1-17.
  11. DOI: https://doi.org/10.55670/fpll.fuen.3.4.1
  12. J. Wang, Z. Liu, C. Ji, and L. Liu, “Heat Transfer and Reaction Characteristics of Steam Methane Reforming in a Novel Composite Packed Bed Microreactor for Distributed Hydrogen Production,” Energies (Basel), vol. 16, no. 11, p. 4347, May 2023, doi: 10.3390/en16114347.
  13. T. Pröll and A. Lyngfelt, “Steam Methane Reforming with Chemical-Looping Combustion: Scaling of Fluidized-Bed-Heated Reformer Tubes,” Energy & Fuels, vol. 36, no. 17, pp. 9502–9512, Sep. 2022, doi: 10.1021/acs.energyfuels.2c01086.
  14. “Hydrogen Production: Natural Gas Reforming,” Office of Energy Efficiency & Renewable Energy. Accessed: Oct. 20, 2024. [Online]. Available: https://www.energy.gov/eere/fuelcells/hydrogen-production-natural-gas-reforming
  15. F. J. Durán, F. Dorado, and L. Sanchez-Silva, “Exergetic and Economic Improvement for a Steam Methane-Reforming Industrial Plant: Simulation Tool,” Energies (Basel), vol. 13, no. 15, p. 3807, Jul. 2020, doi: 10.3390/en13153807.
  16. N. MARUOKA, H. PURWANTO, and T. AKIYAMA, “Exergy Analysis of Methane Steam Reformer Utilizing Steelmaking Waste Heat,” ISIJ International, vol. 50, pp. 1311–1318, Apr. 2010.
  17. O. F. Dilmac and S. K. Ozkan, “Energy and exergy analyses of a steam reforming process for hydrogen production,” International Journal of Exergy, vol. 5, no. 2, p. 241, 2008, doi: 10.1504/IJEX.2008.016678.
  18. Z. Wang, J. Mao, Z. He, and F. Liang, “Energy-exergy analysis of an integrated small-scale LT-PEMFC based on steam methane reforming process,” Energy Convers Manag, vol. 246, p. 114685, Oct. 2021, doi: 10.1016/j.enconman.2021.114685.
  19. J. Ahn, “Heat Transfer and Thermal Efficiency in Oxy-Fuel Retrofit of 0.5 MW Fire Tube Gas Boiler,” Processes, vol. 12, no. 5, p. 959, May 2024, doi: 10.3390/pr12050959.
  20. A. Koopman, A. Rao, B. Marini, C. M. Soares, and D. G. Bogard, “GAS TURBINES IN SIMPLE CYCLE & COMBINED CYCLE APPLICATIONS,” National Energy Technology Laboratory .
  21. R. Weber, J. P. Smart, and W. vd Kamp, “On the (MILD) combustion of gaseous, liquid, and solid fuels in high temperature preheated air,” Proceedings of the Combustion Institute, vol. 30, no. 2, pp. 2623–2629, Jan. 2005, doi: 10.1016/j.proci.2004.08.101.
  22. C. Robinson and D. B. Smith, “The auto-ignition temperature of methane,” J Hazard Mater, vol. 8, no. 3, pp. 199–203, Jan. 1984, doi: 10.1016/0304-3894(84)85001-3.
  23. “Pipeline Basics & Specifics About Natural Gas Pipelines,” Sep. 2015. Accessed: Oct. 20, 2024. [Online]. Available: https://pstrust.org/wp-content/uploads/2015/09/2015-PST-Briefing-Paper-02-NatGasBasics.pdf
  24. A. Bejan, G. Tsatsaronis, and M. Moran, “Exergy Analysis,” in Thermal Design & Optimization, John Wiley & Son, inc, 1996, ch. 3, pp. 116–117.
  25. M. MORAN, H. SHAPIRO, and D. BOETTNER, “Closed System Exergy Balance,” in FUNDAMENTALS OF ENGINEERING THERMODYNAMICS, 8th ed., Wiley, 2014, ch. 7, pp. 379–413.
  26. M. Moran, H. Shapiro, and D. Boettner, “Reacting Mixtures and Combustion,” in FUNDAMENTALS OF ENGINEERING THERMODYNAMICS, 8th ed., 2014, ch. 13, pp. 844–854.
  27. I. Dincer and M. A. Rosen, “Chemical exergy,” in Exergy, Elsevier, 2021, pp. 37–60. doi: 10.1016/B978-0-12-824372-5.00003-8.
  28. R. Pal, “Chemical exergy of ideal and non-ideal gas mixtures and liquid solutions with applications,” International Journal of Mechanical Engineering Education, vol. 47, no. 1, pp. 44–72, Jan. 2019, doi: 10.1177/0306419017749581.
  29. L. Chen, Z. Qi, S. Zhang, J. Su, and G. A. Somorjai, “Catalytic Hydrogen Production from Methane: A Review on Recent Progress and Prospect,” Catalysts, vol. 10, no. 8, p. 858, Aug. 2020, doi: 10.3390/catal10080858.
  30. D. Kaya, F. Çanka Kılıç, and H. H. Öztürk, “Energy Efficiency in Boilers,” 2021, pp. 265–306. doi: 10.1007/978-3-030-25995-2_9.
  31. “Purchasing Energy-Efficient Large Commercial Boilers,” Federal Energy Management Program. Accessed: Oct. 22, 2024. [Online]. Available: https://www.energy.gov/femp/purchasing-energy-efficient-large-commercial-boilers
  32. G. Ludwig, S. Meschkat, and B. Stoffel, “Design Factors Affecting Pump Efficiency,” in Energy Efficiency in Motor Driven Systems, Berlin, Heidelberg: Springer Berlin Heidelberg, 2003, pp. 532–538. doi: 10.1007/978-3-642-55475-9_77.
  33. A. Martin-Candilejo, D. Santillán, and L. Garrote, “Pump Efficiency Analysis for Proper Energy Assessment in Optimization of Water Supply Systems,” Water (Basel), vol. 12, no. 1, p. 132, Dec. 2019, doi: 10.3390/w12010132.
  34. D. L. Millar, “On the Determination of Efficiency of a Gas Compressor,” Energies (Basel), vol. 17, no. 13, p. 3260, Jul. 2024, doi: 10.3390/en17133260.
  35. S. N. Subramanya, V. S. C. Reddy, and V. Madav, “Performance Evaluation of Various Ni-Based Catalysts for the Production of Hydrogen via Steam Methane Reforming Process,” in RAiSE-2023, Basel Switzerland: MDPI, Jan. 2024, p. 138. doi: 10.3390/engproc2023059138.
  36. H.-G. Park, S.-Y. Han, K.-W. Jun, Y. Woo, M.-J. Park, and S. K. Kim, “Bench-Scale Steam Reforming of Methane for Hydrogen Production,” Catalysts, vol. 9, no. 7, p. 615, Jul. 2019, doi: 10.3390/catal9070615.
  37. “How Gas Turbine Power Plants Work,” Office of Fossil Energy and Carbon Management. Accessed: Oct. 26, 2024. [Online]. Available: https://www.energy.gov/fecm/how-gas-turbine-power-plants-work#:~:text=A%20simple%20cycle%20gas%20turbine,of%2060%20percent%20or%20more.
  38. N. Hajjaji, M.-N. Pons, A. Houas, and V. Renaudin, “Exergy analysis: An efficient tool for understanding and improving hydrogen production via the steam methane reforming process,” Energy Policy, vol. 42, pp. 392–399, Mar. 2012, doi: 10.1016/j.enpol.2011.12.003.
  39. A. SIMPSON and A. LUTZ, “Exergy analysis of hydrogen production via steam methane reforming,” Int J Hydrogen Energy, vol. 32, no. 18, pp. 4811–4820, Dec. 2007, doi: 10.1016/j.ijhydene.2007.08.025.
  40. M. Rosen, “Thermodynamic investigation of hydrogen production by steam-methane reforming,” Int J Hydrogen Energy, vol. 16, no. 3, pp. 207–217, 1991, doi: 10.1016/0360-3199(91)90003-2.
  41. J. Lambert, “Analysis of oxygen-enriched combustion for steam methane reforming (SMR),” Energy, vol. 22, no. 8, pp. 817–825, Aug. 1997, doi: 10.1016/S0360-5442(96)00170-3.