Thermo-economic analysis of a novel integrated structure for liquefied natural gas production using photovoltaic panels
26 Apr 2021-Journal of Thermal Analysis and Calorimetry (Springer International Publishing)-Vol. 145, Iss: 3, pp 1509-1536
TL;DR: In this paper, a solar energy and natural gas storage method was developed for transfer to faraway regions for demand response by using the DMR compression refrigeration cycle, Kalina power production cycle, and photovoltaic solar panels for the climate of Chabahar coastal city in Southern Iran.
Abstract: As natural gas is not uniformly distributed in different regions of the world, and gas tanks are concentrated in specific geographical areas, gas transfer is a key gas-related industry that greatly contributes to the expansion of this energy carrier's use. For long distances, the use of pipeline transport is uneconomical in practice, and alternative methods should be adopted. From among alternative methods to pipeline transport, natural gas liquefaction is the best and most economic one. A major challenge to the expansion of liquefied natural gas (LNG) use is the energy-consuming process of its production. The liquid gas production process, like other liquefaction processes, consumes considerable amounts of energy. In this paper, a solar energy and natural gas storage method was developed for transfer to far-away regions for demand response by using the DMR compression refrigeration cycle, Kalina power production cycle, and photovoltaic solar panels for the climate of Chabahar coastal city in Southern Iran. The dissipated heat from the DMR compression refrigeration cycle was used as the heat source for the Kalina cycle. The coefficient of performance, specific energy consumption, and exergy yield of the developed integrated structure were 3.201, 0.2293 kWh kg−1 LNG, and 42.77%, respectively. The exergy analysis of this integrated structure showed that the largest shares of exergy destruction belonged to solar panels (86.29%) and heat exchangers (6.51%), respectively. The economic analysis of the integrated structure revealed that the payback period, the prime cost of product, and additive value equaled 2.061 years, 0.2500 US$ kg−1 LNG, and 0.1156 US$ kg−1 LNG, respectively. The results of sensitivity analysis demonstrated that, for the capital cost of 2100 MMUS$ and less, the payback period is < 4 years.
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TL;DR: In this paper , an innovative integrated structure for the cogeneration of biomethane (bioCH4) and liquid carbon dioxide (CO2) by unrefined biogas and exhaust fumes from power plants is developed.
Abstract: Nowadays, it is undeniable that applying renewable energy kinds with the approach of maximizing the performance of energy systems owing to the rising trend of energy demand in the world. In this research, an innovative integrated structure for the cogeneration of biomethane (bioCH4) and liquid carbon dioxide (CO2) by unrefined biogas and exhaust fumes from power plants is developed. The cryogenic biogas upgrading process and CO2 capture cycle are used for the treatment of unrefined biogas and the exhaust fumes from the power plants, respectively. The absorption–compression cooling process and organic Rankine/Kalina power units through geothermal energy are used to provide refrigerate and power. The present integrated process generates 0.8434 kg/s bioCH4 and 2.631 kg/s liquid CO2 by receiving 2.368 kg/s untreated biogas, 21.32 kg/s flue gas, and 7922 kW heat flow from geothermal energy. The thermal and total exergy efficiencies of the hybrid system are achieved at 59.94% and 73.10%, respectively. Exergy analysis depicts that the heat exchangers (4043 kW) and distillation columns (1857 kW) have the most exergy destruction in the among of equipment, which is 39.12% of the total system destruction. The heat exchanger network related to the multi-stream exchanger HE16 is extracted by pinch method. The economic assessment illustrates that the return period and the prime cost of the product are equal to 4.45 years and 0.8189 US$/ m3 bio-methane, respectively. The sensitivity investigation illustrates that the total thermal efficiency increases up to 72.50% and geothermal heat duty decreases to 7808 kW with the increase of methane composition in the untreated biogas from 55 mol% to 75 mol%. The return period increases up to 2.235 years and the net annual benefit decrease to 16.73 MMUS$/year when the bio-methane cost decreases from 2.5 US$/m3 to 0.5 US$/m3.
16 citations
TL;DR: In this paper , the authors developed a novel integrated structure for the simultaneous production of portable and relatively clean liquid fuels from COG and power plant exhaust gases, which includes a CO2 capture unit to separate carbon dioxide from exhaust gases.
10 citations
TL;DR: In this article, a novel hybrid system for energy storage and freshwater production using air compression and liquefaction system, ejector refrigeration cycle (ERC), thermal multi-effect desalination (MED) system, and natural gas combustion unit (GCU) is developed.
Abstract: This study aims to investigate an innovative hybrid structure of electricity storage at off-peak hours and its application at on-peak hours. In this paper, a novel hybrid system for energy storage and freshwater production using air compression and liquefaction system, ejector refrigeration cycle (ERC), thermal multi-effect desalination (MED) system, and natural gas combustion unit (GCU) is developed. The wasted heat of the liquefaction cycle is stored at off-peak hours to provide heat to the ERC and thermal desalination system and preheat the inlet streams to the turbines at on-peak hours. Also, wasted refrigeration of liquid air stream and refrigeration resulting from liquefied natural gas (LNG) regasification operations are stored at on-peak hours and are utilized in compressed air liquefaction at off-peak hours. This integrated structure produces 83.12 kg/s liquid air and 38.91 kg/s freshwater at off-peak hours with 58.24 MW power consumption. During on-peak hours, the liquid air along with 2.681 kg/s LNG enters the turbines after preheating and combustion and generated 122.6 MW power. Round-trip and storage efficiencies are obtained as 64.91% and 75.96%, respectively. Also, the exergy efficiencies of the energy storage system at off-peak hours, energy production system at on-peak hours and the whole system are estimated as 78.13%, 75.85%, and 65.92%, respectively. The results of the exergy study illustrate the reactors (43.37%), heat exchangers (26.76%), and throttle valves (10.58%) have the highest contribution to exergy destruction in the proposed combined structure, respectively. This study provides the refrigeration cycle integration with process core as hot and cold composite curves and pinch analysis. Pinch investigation is conducted on the system multi-stream exchangers and the heat exchanger networks are extracted. The economic analysis illustrates that the investment return period, the levelized cost of the product, and net annual benefit in the hybridized system are 4.877 years, 0.0919 US$/kWh, 78.38 MMUS$/year, respectively. The results of sensitivity analysis indicate the round-trip efficiency increases up to 65.32% by raising the pressure of the on-peak power generation cycle.
7 citations
TL;DR: In this paper , an integrated structure for hydrogen liquefaction and storage by employing the LNG regasification process for precooling and four multi-component refrigerant cycles for liquid hydrogen for electrical power generation is proposed.
Abstract: Liquid natural gas (LNG) regasification and fuel cells can be employed to supply the required precooling and electrical power for hydrogen liquefaction, respectively. Such an approach helps reduce the process complexity and the number of equipment, total costs, and carbon footprints, and enhance the controllability of the process. This paper proposes an integrated structure for hydrogen liquefaction and storage by employing the LNG regasification process for precooling and four multi-component refrigerant cycles for liquefaction. Molten carbonate fuel cells, gas turbines power cycles, the two-stage organic Rankine cycle, and the carbon dioxide power cycle are used for supplying the electrical power. A liquid hydrogen production capacity of 1766 kmol/h and 1576.7 MW electrical power generation are attained in this integrated process. The coefficient of performance, specific energy consumption, and specific power consumption of the integrated structure are calculated to be 0.175, 4.772 kWh/kgLH 2 , and 3.872 kWh/kgLH 2 , respectively. The exergy efficiency of 83.03% and the exergy destruction of 47.87 MW are obtained based on the exergy analysis. The maximum shares of exergy destruction are attributed to the heat exchangers, gas turbines, and fuel cells with the magnitudes of 45.43%, 24.75%, and 10.93%, respectively. The prime cost of product and rate of return are calculated to be 0.0840 US$/kWh and 24.02%, respectively. According to the sensitivity analysis, it is found that increasing the molar fraction of helium in the multi-component refrigerant cycle from 81.31% to 93.61% leads to a reduction in the net power production (151.2 MW) and total exergy efficiency (81.39%) of the proposed process. Using the multi-objective genetic algorithm method, the total exergy efficiency and the rate of return are optimized to be 86.32% and 29.66%, respectively. • A novel hydrogen storage structure is designed by hydrogen liquefaction system. • Fuel cells, LNG regasification unit and gas/CO 2 /ORC unit are efficiently integrated. • Integrated process can produce 1766 kmol/h liquid hydrogen and 1576.7 MW power. • Exergy efficiency and irreversibility of the hybrid system are 83.03% and 47.87 MW. • The economic evaluation and NSGA-II algorithm are used to evaluation of hybrid system.
7 citations
TL;DR: In this article, a novel integrated system for cogeneration of liquefied natural gas (LNG) and hot water using two stages ejector refrigeration system (ERC) and low-temperature organic Rankine cycle (ORC) is developed.
7 citations
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841 citations
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Abstract: SUMMARY
In this paper, five conventional LNG processes were investigated by energy and exergy analysis methods. On the basis of the energy analysis, three-stage process of Linde AG and Stat oil (mixed fluid cascade [MFC]) has less energy consumption than the other ones (0.254 kWh/kg liquefied natural gas). Also, coefficient of performance of the cycles of this process is higher compared with the other ones. Exergy analysis results showed that the maximum exergy efficiency is related to the MFC process (51.82%). However, performance of the MFC process in terms of quality and quantity of energy consumption is considerable. But using three cycles in this process needs more components and consequently more fixed costs. In this study, sensitivity of coefficient of performance, specific energy consumption, and indexes of exergy analysis were also analyzed versus important operating variables for all cases. Copyright © 2014 John Wiley & Sons, Ltd.
104 citations