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Capturing and Utilizing CO2 from Ethanol: Adding Economic Value and Jobs to Rural Economies and Communities While Reducing Emissions statute represent two additional state/provincial LCFS policies within the same region that present potential additional opportunities to incentivize carbon capture from ethanol production. These jurisdictions will be evaluating ARB’s rulemaking for guidance, underscoring how the impact of California’s emerging regulatory framework will extend far beyond the state. Finally, as the largest importer of U.S. ethanol, Canada is currently developing a national Clean Fuels Standard to achieve 30 million MT of annual CO2 emissions reductions by 2030, which would extend LCFS policies beyond the province of British Columbia22. Depending on how Canada implements this national standard, it could serve as an additional market driver for carbon capture deployment in the U.S. biofuels industry.23 Conclusion Widespread deployment of carbon capture represents an important next step in the commercial evolution of the biofuels industry, which has a history of innovation to reduce energy and water use, drive down costs, generate new sources of revenue from value-added byproducts, and lower its carbon intensity. As the industry has improved energy efficiency and lowered emissions, ethanol producers have sought diversity and increased revenue from the development and marketing of byproducts that add value beyond the ethanol itself. Carbon capture presents a further opportunity for the biofuels industry to generate additional economic returns from the oil industry’s purchase of CO2 and from permanent and safe geologic storage of CO2 through EOR and in saline formations. However, up-front costs of installing carbon capture, compression, and dehydration and building out new pipeline infrastructure limit further commercial deployment. Federal and state policies could help bridge the financial gap and reduce risk, attracting private capital to invest in carbon capture and CO2 pipeline projects that serve the ethanol industry, which will in turn foster further innovation and cost reductions. 22 Environment and Climate Change Canada (2017), Clean Fuel Standard: Discussion Paper Available at: https://www.ec.gc.ca/lcpe-cepa/default. asp?lang=En&n=D7C913BB-1 [Accessed July 14, 2017]. 23 Dickinson C (2016) 2016 Top Markets Report: Renewable Fuels (International Trade Association). The results of the analysis in this paper show that revenue from the sale of CO2 for EOR, combined with the proposed federal 45Q tax credit and complemented by eligibility for tax-exempt private activity bonds and master limited partnerships, could enhance the feasibility of deploying carbon capture from ethanol production and the necessary pipeline infrastructure to transport that CO2 to oilfields where it can be put to beneficial use and stored. These federal policies also have the potential to support further geologic storage of CO2 from ethanol in saline formations to achieve even greater emissions reductions. State low carbon fuels policies such as the California LCFS could also help drive private investment in large-scale carbon management by ethanol producers seeking to comply with LCFS requirements by capturing and storing CO2 from fermentation. However, California and other jurisdictions need to develop accompanying regulatory frameworks that enable the industry to establish a commercially viable carbon capture and storage business model around LCFS compliance. The capture of biogenic CO2 from fermentation in ethanol production can play a key role in scaling up carbon management for domestic energy production and geologic storage, thus contributing to American energy independence, protecting and creating high-paying jobs and significantly reducing net carbon emissions. Appendix: CO2 Pipeline Assumptions and Cost Model GPI and IHR utilized the National Energy Technology Laboratory’s (NETL) CO2 Transport Cost Model24, modified by GPI for this application, to calculate detailed breakdowns of capital and operating costs of CO2 pipelines in two scenarios prepared for the Work Group.25 24 Timothy Grant & David Morgan, National Energy Technology Laboratory. FE/NETL CO2 Transport Cost Model. DOE/NETL-2014/1667. July 11, 2014. 25 Martin Dubois, Dane McFarlane and Tandis Bidgoli, CO2 Pipeline Cost Analysis Utilizing and Modified FE/NETL Cost Model Tool, poster presented at the Carbon Storage and Oil and Natural Gas Technologies Review Meeting, Pittsburgh PA, August 3, 2017. Page 27 Prepared by the State CO2-EOR Deployment Work GroupPDF Image | Capturing and Utilizing CO2 from Ethanol
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