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Auto-Thermal Reforming CC¤

Introduction¤

In the current landscape of technological advancements, Autothermal Reforming (ATR) represents a viable method for the reforming of methane. This process employs both oxygen and steam to achieve partial oxidation of methane within reforming tubes 2. Notably, the ATR system operates at a higher temperature compared to Steam Methane Reforming (SMR) 3, thereby enhancing the conversion efficiency of methane.

The principal distinction between Autothermal Reforming (ATR) and Steam Methane Reforming (SMR) technologies lies in the employment of high-purity oxygen in ATR, as illustrated in Figure 1b. In the ATR process, a mixture of natural gas, steam, and oxygen is introduced. This blend not only undergoes reforming reactions but also facilitates partial combustion of natural gas within the reforming tubes to supply the necessary energy for the reforming process. Although the production cost of hydrogen via ATR is elevated compared to SMR, primarily due to the expenses associated with oxygen production, ATR offers significant advantages. Notably, the syngas and flue gas streams, emanating from the boiler unit, are not diluted with nitrogen. Consequently, CO2 removal and liquefaction processes are simplified in ATR compared to SMR, as detailed in the Methods section. This attribute renders ATR more advantageous for carbon capture applications.1

Simplified block diagrams of hydrogen production technologies: (b) ATR natural gas reforming
Simplified block diagrams of hydrogen production technologies: (b) ATR natural gas reforming

In the configuration of ATR coupled with a carbon capture system, the hydrogen-rich syngas produced is subsequently directed to the CO2 removal unit. Within this unit, diglycolamine (DGA) serves as the solvent for the extraction of CO2 from the syngas

ES Model Parameters¤

All the parameters concerning the Auto-Thermal Reforming CC are listed in the table below.

entry_key value unit sets source_reference
CO2_C (layer) 0.38 kg_CO2 CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"
CO2_E (layer) 0.042 kg_CO2 CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"
H2_HP (layer) 1 kWh CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"
NG_HP (layer) -1.583 kWh CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"
c_inv 1062.44 CAD/kW CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"
c_maint 53.12 CAD/kW/y CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"
c_p 0.85 - CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"
lifetime 30 y CAN Slaymaker, Amara, (2021): "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"

References¤

Data Sources
Slaymaker, Amara. (2021). "Demographic and Geographic Region Definition in Energy System Modelling. A Case Study of Canada's Path to Net Zero Greenhouse Gas Emissions by 2050 and the Role of Hydrogen"

  1. Khojasteh Salkuyeh, Yaser, et al. “Techno-economic analysis and life cycle assessment of hydrogen production from natural gas using current and emerging technologies.” Int. J. Hydrogen Energy, vol. 42, no. 30, 27 July 2017, pp. 18894-909, doi:10.1016/j.ijhydene.2017.05.219. ⧉ ↩

  2. Aasberg-Petersen, Kim, et al. “Recent developments in autothermal reforming and pre-reforming for synthesis gas production in GTL applications.” Fuel Process. Technol., vol. 83, no. 1, 15 Sept. 2003, pp. 253-61, . ↩

  3. Holladay, J. D., et al. “An overview of hydrogen production technologies.” Catal. Today, vol. 139, no. 4, 30 Jan. 2009, pp. 244-60, . ↩