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研究生： 霍 安
Nguyen, Le Quoc Hoan
論文名稱： 稀釋氨水吸收二氧化碳之能源及環境效益
Energy Efficiency and Synergetic Environmental Benefits of CO2 Capture by Aqueous Ammonia
指導教授： 汪上曉
Wong, David Shan-Hill
口試委員: 劉佳霖
Liu, Jia-Lin
張煖
Chang, Hsuan
談駿嵩
Tan, Chung-Sung
鄭西顯
Jang, Shi-Shang
學位類別： 博士
Doctor
系所名稱： 工學院 - 化學工程學系
Department of Chemical Engineering
論文出版年： 2019
畢業學年度： 107
語文別： 英文
論文頁數： 117
中文關鍵詞： 吸收二氧化碳 、稀釋氨水 、稀蒸氣再壓縮 、富蒸氣再壓縮
外文關鍵詞： dilute aqueous ammonia, energy reduction, new stripper configuration, lean vapor recompression, rich vapor recompression
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    • 在燃燒後氣體二氧化碳捕獲技術稀，釋氨水是一種習知代替溶劑，然而，溶劑再生需要耗費大量能源，仍舊是此方法在廣泛應用發展需面臨的嚴峻挑戰。本研究利用優化貧液溶劑閃蒸之壓力，及汽提塔中氨水濃度與低二氧化碳負載，提出一種先進稀蒸氣再壓縮程序可取代再沸器的功能，發現所需要的總等效功為0.167千瓦-小時/公斤二氧化碳，不須由電力循環中獲取低壓蒸汽，二氧化碳捕獲工廠與發電廠間的交互作用可以解除。
    藉由富蒸汽與稀蒸汽再壓縮組合的修正，可進一步提升二氧化碳捕獲工廠的能源效率，需要的總等效功降為0.123千瓦-小時/捕獲公斤二氧化碳，相當於節省10%能源損失，相當於近期文獻發表26-54%降低能耗水準。
    利用IECM v9.5 及 ASPEN Plus v8.4軟體模擬，一座500百萬瓦的碎燃媒電廠，以氨水捕獲二氧化碳同時捕獲硫氧化物的技術與經濟設備評估及各種硫成分，結果顯示，共捕獲程序相較於一般廢氣除硫碳捕獲電廠，可同時降低設備成本及操作成本。對於高硫份煤炭電廠而言，年度總操作成本及電能獲利損失，在共捕獲程序較高。然而，即便對於一個長期操作的電廠而言，藉由節省的設備投資成本可以抵銷此損失。對共捕獲程序來說，即使使用高硫份燃煤，應用富蒸汽與稀蒸汽再壓縮程序組合，使得操作成本及電能損失同時下降，且設備支出亦同時減少。
    再者，以單醇胺溶液作為低硫份燃煤的吸收劑，進行共捕獲程序的效能分析，結果顯示電能成本節省非常有限，由於高胺液成本所致。一般氨水作為廢氣除硫及碳捕獲程序相較於單醇胺程序不具競爭力。但是，對於共捕獲程序而言，一般氨水與單醇胺程序是沒有太大差別，當使用富蒸汽與稀蒸汽再壓縮程序組合，電能成本及碳捕獲成本分別為，美金108元/百萬瓦-小時及美金50.3元/噸二氧化碳，即使是高硫份燃煤仍優於單純胺程序；低硫份燃煤，為美金117元/百萬瓦-小時及美金78.5元/噸二氧化碳。
    本論文經由精細整合及強化，利用稀釋氨水來改善二氧化碳捕獲程序，使其相較於熟用的醇胺程序來說，成為更具競爭力之取代溶劑。

    Dilute aqueous ammonia (NH3) is one of the promising alternative solvents for post-combustion carbon dioxide capture technology. However, substantial energy consumption for solvent regeneration is still a critical challenge for the widespread deployment of this method. In this work, by optimizing the pressures of the lean solvent flash and the stripper, NH3 concentration and lean CO2 loading, an advanced lean vapor recompression process was developed. The total equivalent work required is found to be 0.167 kWh/kg CO2. Interestingly, the need of reboiler is completely eliminated. As low-pressure steam does not have to be extracted from the power cycle, an interaction between the capture plant and the power plant can be decoupled.
    The energy efficiency of this CO2 capture can be further improved by combining rich vapor recompression and lean vapor recompression modifications. The total equivalent work required was reduced to 0.123 kWh/kg of CO2 captured, which is equivalent to about 10% energy penalty. This amounts to 26~54% reduction from recent literature reports.
    The techno-economic feasibility of co-capture of sulfur oxides with carbon dioxides using ammonia was evaluated. Simulations and economic assessments for a 500 MW pulverized coal-fired power plant with various sulfur contents were carried out using the IECM v9.5 and ASPEN Plus v8.4. It was found that the co-capture process will reduce both capital and operating cost compared to the standard power plant with flue gas desulfurization and carbon dioxide capture. For the high sulfur coal, the annual total operation cost and loss in electricity profit in the co-capture case was higher, however it would be offset by savings in capital investment even if the power plant will have a long operating life. By applying the combined rich and lean vapor recompression process to the co-capture case, both operating costs and loss in electricity were reduced as well as the capital expenditure was reduced even in the high sulfur case.
    Furthermore, the performance analysis of the co-capture process by using mono-ethanolamine solution was also conducted for the case of low sulfur coal. Results showed that very little savings in the cost of electricity and carbon dioxide avoidance cost can be achieved when co-capture was used because of the higher costs of amines. The standard ammonia process with flue gas desulfurization and carbon dioxide capture was not competitive to the mono-ethanolamine process. However, with co-capture, the standard ammonia process was equivalent to the mono-ethanolamine process. When rich plus lean vapor recompression was used, the cost of electricity and carbon dioxide avoidance cost (US$108/MWh and US$50.3/tonne CO2) even for the high sulfur case was better than those of mono-ethanolamine process for low sulfur case (US$117/MWh and US$78.5/tonne CO2).
    In this thesis, through careful integration and intensification, we have improved the carbon dioxide capture process using aqueous ammonia so that it became a very competitive alternative solvent to the existing amine process.

    Acknowledgements i 摘要 ii Abstract iv Table of Contents vi List of Figures xi List of Tables xv Chapter 1: Introduction 1 1.1. Research background 1 1.1.1. Mitigating climate change 1 1.1.2. Carbon capture technologies 2 1.2. Post-combustion CO2 capture technology using chemical solvent 6 1.2.1. Process concept 6 1.2.2. Chemical solvents 7 1.3. Research objectives and structure of this work 9 Chapter 2: Literature review 10 2.1. CO2 capture technologies using aqueous ammonia 10 2.1.1. Powerspan’s ECO2 process 10 2.1.2. RIST’s ammonia-based CO2 capture process 11 2.1.3. Alstom’s chilled ammonia process (CAP) 12 2.1.4. CSIRO’s aqueous ammonia process (AAP) 14 2.1.5. SRI International’s mixed-salt capture technology 15 2.2. Modelling ammonia processes 16 2.2.1. Equilibrium model 16 2.2.2. Rate-based model 17 2.3. Process integrations to improve the energy efficiency of CO2 capture 19 2.3.1. Rich solvent splitting 19 2.3.2. Inter-cooled absorber 20 2.3.3. Multi-pressure stripper 21 2.3.4. Inter-heating stripper 22 2.3.5. Flash stripper 23 2.3.6. Rich vapor recompression 24 2.3.7. Lean vapor recompression 25 2.4. Co-capturing acid pollutant (SO2) 26 2.4.1. Amine-based capture process 26 2.4.2. Aqueous ammonia-based capture process 29 Chapter 3: Aqueous ammonia-based CO2 capture process using lean vapor recompression configuration 31 3.1. Introduction 31 3.2. Process description 32 3.2.1. Base case process 32 3.2.2. Lean vapor recompression configuration 34 3.2.3. Advanced LVR configuration 35 3.3. Methodology 37 3.3.1. Simulation model 37 3.3.2. Model verification 40 3.3.2.1. Stripper column: rate-based or equilibrium models? 40 3.3.2.2. Verifying the simulation model 41 3.3.3. Quantifying system performance 42 3.3.4. Process design 43 3.4. Results and discussion 44 3.4.1. Effect of LSF pressure 44 3.4.2. Effect of stripper pressure 46 3.4.3. Effect of lean CO2 loading 48 3.4.4. Effect of NH3 concentration 50 3.4.5. Performance of advanced LVR configuration 53 3.5. Conclusion 55 Chapter 4: Aqueous ammonia-based CO2 capture process using the combined rich and lean vapor recompression configuration 56 4.1. Introduction 56 4.2. Methodology 57 4.2.1. Process description 57 4.2.1.1. Rich vapor recompression configuration 57 4.2.1.2. Combined RVR and LVR configuration 58 4.2.2. Energy evaluation 59 4.2.3. Optimization design for the combined RLVR process 60 4.3. Results and discussion 61 4.3.1. Process modifications 61 4.3.1.1. RVR process 61 4.3.1.2. Combined RLVR process 62 4.3.1.3. Process comparison 65 4.3.2. Process optimization of combined RLVR process 66 4.3.2.1. Effect of stripper pressure 67 4.3.2.2. Effect of lean CO2 loading 68 4.3.2.3. Effect of NH3 concentration 70 4.3.3. Process assessment 72 4.4. Conclusion 75 Chapter 5: Techno-economic assessment of the simultaneous SOx and CO2 co-capture process 76 5.1. Introduction 76 5.2. Power plant performance 78 5.2.1. Power plant flowsheet 78 5.2.2. Co-capture process by dilute aqueous ammonia 81 5.2.3. Co-capture process by amine 82 5.3. Methodology 86 5.3.1. Simulation model 86 5.3.1.1. Aqueous NH3-based capture process 86 5.3.1.2. MEA-based capture process 88 5.3.2. Costing model 89 5.3.2.1. Power penalty calculation 89 5.3.2.2. Economic analysis 90 5.4. Results and discussion 93 5.4.1. Effect of different S content coals 93 5.4.2. Process improvement 95 5.4.3. Techno-economic comparison of NH3-based and MEA-based co-capture processes 99 5.4.3.1. Technical performance of power plant integrated with capture plant 99 5.4.3.2. Economic assessment 103 5.5. Conclusion 107 Chapter 6: Summary 109 References 111

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