CCS-EOR Projects Research Articles

Front End Engineering Design Study for Carbon Capture at a Natural Gas Combined Cycle Power Plant in California

The Electric Power Research Institute (EPRI), California Resources Corporation (CRC), and Fluor Corporation are conducting a Front-End Engineering Design (FEED) study to determine the technical and economic feasibility of a retrofit, post-combustion, carbon capture technology on a commercially operating, natural gas-fired, combined cycle (NGCC) power plant in California. Fluor’s Econamine FG PlusSM (EFG+) process is being designed to capture CO2 from the flue gas produced by CRC’s 550 MWe Elk Hills Power Plant (EHPP), a NGCC unit located in the Elk Hills Oil Field near Tupman, Kern County, California. The design basis is to route about 79% of the flue to Fluor’s EFG+ plant with the remaining 21% vented as normal through the stack. Steam is supplied to the capture plant from a gas-fired package boiler whose flue gas is combined with the EHPP flue gas as it’s routed to the EFG+ process. The EFG+ process then captures 90% of the total combined inlet CO2. Overall, about 4,000 tonne (t) CO2/day will be captured and delivered at 97+ mol% purity and 160 bar pressure for use by CRC for CO2 enhanced oil recovery (EOR) or CO2 storage in nearby reservoirs. CRC is one of the largest oil producers in California (132,000 barrels oil equivalent/day) and is pursuing CO2-EOR to increase oil output from California’s Elk Hills field. EHPP is unique in that CRC owns and operates the NGCC power plant, provides its natural gas fuel supply, uses much of its steam and electrical output, and will use the captured CO2 for either CO2 enhanced oil recovery or CO2 storage. The regulatory and tax incentives at the California State level and at the U.S. Federal level combined with the use of CO2 for enhanced oil recovery by CRC, provide a significant commercial interest in using the captured CO2 for enhanced oil recovery in California’s Elk Hills region. Permitting work around CCS with EOR in Elk Hills was initiated in 2010, including an expansive Monitoring, Reporting and Verification (MRV) plan. Regulatory outreach and execution for the current CCS-EOR project were initiated in early 2018 via direct engagement with multiple state and federal agencies. Assuming the FEED study results are favourable, this project could lead to deployment of one of the world’s largest carbon capture processes on a power plant – coal- or gas-fired.

Exploring the potential of carbon capture and storage-enhanced oil recovery as a mitigation strategy in the Colombian oil industry

The use of CO2 for enhanced oil recovery (CO2-EOR) is a promising alternative for reducing the cost of carbon capture and storage (CCS). In this study the techno-economic potential of integrated CCS-EOR projects for reducing greenhouse gas (GHG) emissions in the Colombian oil industry is estimated. For this purpose, a source-sink matching process is carried out, including CO2 capture potentials in sources from the petroleum, cement, power generation, and bioethanol industries, as well as from the CO2 storage in suitable oil fields for EOR. The results indicate that a total of 142 million tons of carbon dioxide (MtCO2) could be stored, while delivering 465 MMbbl through five CCS-EOR projects in four clusters identified around the country. The levelised cost for capture ranged between 12–209 €/tCO2, followed by the cost of CO2 during EOR operations with a variation of 24–59 €/tCO2, and finally the CO2 transport, from 1 €/tCO2 to 23 €/tCO2. The CO2 mitigation potential of CCS-EOR represents 25 % of the forecasted oil industry emissions in Colombia for the period of 2025–2040. As compared to the intended nationally determined contribution (INDC) target set by the Colombian government, CCS-EOR projects could contribute 7 % of the total accumulated emissions reductions by 2040.

A cash flow model of an integrated industrial CCS-EOR project in a petrochemical corridor: A case study in Louisiana

Petroleum refineries and petrochemical plants are major CO2 sources, however, they are also significant capital and employment assets that are unlikely to be replaced in the near term. As a result, nations and states that are interested in reducing the carbon intensity of their economies will need to find ways to reduce the emissions of their existing industrial capacity. Industrial carbon capture provides one potential mechanism for reducing the carbon intensity of existing industrial facilities, however, an economically feasible capture system requires that the captured CO2 be integrated into a system of transport and storage with income generated either through tax credits, enhanced oil recovery (EOR), or both. Here, we present a cash-flow model of an integrated system with industrial capture, pipeline transport, and EOR, and we parameterize the model with data from Louisiana. Given a $50/bbl oil price, an integrated capture, transport and EOR system that uses ethylene oxide production, ammonia production, or natural gas processing as sources is predicted to have a net present value of about $500 million; hydrogen-based capture has a cash flow of −$214 given the same assumptions. Further, we find that the recent 45Q Tax Credit expansion has a positive impact on the cash flow of the system but does not change the overall profitability of the systems under the specified assumptions such that without the tax credits natural gas processing, ammonia production and ethylene oxide production-based capture systems remain cost-effective, while hydrogen-based capture remains unprofitable with or without the tax credit.

Analysis and selection of CO₂ sources for CCS-EOR projects in oil fields clusters in Poland

Analysis and selection of CO₂ sources for CCS-EOR projects in oil fields clusters in Poland

The research of net carbon reduction model for CCS-EOR projects and cases study

This paper develops a calculation model of net carbon reduction for CCS-EOR, which is calculated by one minus the new generation CO2 by energy consumption during the processes of capture, transportation, injection and the recovery, meanwhile adding the re-injection CO2 content. By taking the CCS-EOR projects with the capacity of 0.5 million tons CO2 per year in the coal-fired power plant, coal chemical plant and chemical fertiliser plant as examples, we calculate the actual emission reductions and energy consumption per ton of CO2 with referencing to the current mainstream technology level. The results show that the net carbon reduction values in the two situations without and with recovery process of associated gas are respectively 0.4965 and 0.3951, 0.7624 and 0.6610, 0.7815 and 0.68 tons CO2, and the energy consumption values are 5.7405 and 6.6117, 2.7095 and 3.5807, 2.49185 and 3.36305 GJ in the three different plants.

The research of net carbon reduction model for CCS-EOR projects and cases study

This paper develops a calculation model of net carbon reduction for CCS-EOR, which is calculated by one minus the new generation CO2 by energy consumption during the processes of capture, transportation, injection and the recovery, meanwhile adding the re-injection CO2 content. By taking the CCS-EOR projects with the capacity of 0.5 million tons CO2 per year in the coal-fired power plant, coal chemical plant and chemical fertiliser plant as examples, we calculate the actual emission reductions and energy consumption per ton of CO2 with referencing to the current mainstream technology level. The results show that the net carbon reduction values in the two situations without and with recovery process of associated gas are respectively 0.4965 and 0.3951, 0.7624 and 0.6610, 0.7815 and 0.68 tons CO2, and the energy consumption values are 5.7405 and 6.6117, 2.7095 and 3.5807, 2.49185 and 3.36305 GJ in the three different plants.

Analysis and selection of CO2 sources for CCS-EOR projects in oil fields clusters in Poland

Analysis and selection of CO2 sources for CCS-EOR projects in oil fields clusters in Poland

Promoting the Carbon Removal in Coal Utilization-A Benefit-Risk Analysis among Full-Chain Carbon Capture and Utilization Project

The full-chain development of CCUS (Carbon Capture, Utilization, and Storage) requires the cooperation of different stakeholders. Focusing on full-chain CCS-EOR (enhanced oil recovery) projects, this study presents a benefit-risk analysis for two kinds of stakeholder (power plant owner and oil field owner). Their interaction (in CO2 capture and utilization) will be reflected in the contract design, in terms of several items referring to price setting and cost sharing. Taking account of uncertainty factors and operational flexibility, benefits and risks for a power plant and an oil field cooperating on a CCS-EOR project can be separately evaluated. The simulation results show that the oil field occupies the dominant position in cooperative CO2 utilization, and that contract design needs to improve the position of power plants, especially in terms of the pricing power of captured CO2. The present approach can help different stakeholders in the CCS value chain to better identify their level of benefit and risk, and to support the negotiation of cost and risk sharing among different stakeholders in full-chain CCS deployment.

Jingbian CCS Project, China: Second Year of Injection, Measurement, Monitoring and Verification

Abstract Jingbian CCS-EOR pilot project is the first full chain CCS-EOR project in China. Sponsored by China Ministry of Science and Technology, Shaanxi Yanchang Petroleum (Group) Co. Ltd started to conduct CO2 capture from its coal chemical company and injected CO2 in Jingbian Field which cooperated with Northwest University from 2012. Our target is to inject at least 10,000 tons CO2 in Jingbian Field of Shaanxi Yanchang Petroleum (Group) Co. Ltd. At the same time, we are developing an integrated MMV (Measurement, Monitoring and Verification) technique to monitor the safety of CO2 sequestration from surface to subsurface by using environmental, geophysical monitoring methods and geological analysis. At this low porosity and low permeability reservoir of Jingbian Field, we planned to inject CO2 in more than 5 wells and tried to get enhanced oil recovery ratio about 5% to 8% and form CO2-EOR techniques and a demonstration pilot project so that we may apply CCS-EOR in Ordos Basin which is the largest oil and gas production basement in China. Jingbian CCS-EOR pilot project is the same as the other CCS projects in the world. It includes site selection, CO2 storage and injection equipment construction, CO2 capture equipment construction, CO2-EOR laboratory tests and MMV study.

The Alberta Carbon Trunk Line and the Benefits of CO2

The Alberta Carbon Trunk Line Update on the Words's Largest Carbon Capture and Storage Project Enhance Energy Inc. (Enhance), located in Alberta, Canada, specializes in Enhanced Oil Recovery (EOR) and Carbon Capture and Storage (CCS). Along with its partner North West Redwater Partnership (NWRP), Enhance has developed a fully integrated CCS project incorporating gasification, CO2 capture, transportation, storage and EOR. The project utilizes proven technology to provide a critical CO2 gathering and distribution infrastructure, which will enable the cost-effective management of CO2 emissions in Alberta, Canada. The project also demonstrates how Alberta's vast bitumen resources can be produced amid tightening environmental standards.At the heart of the proposed project is the Alberta Carbon Trunk Line (ACTL), a 16”, 240km pipeline, which will be fully operational in 2015. Laterals have been designed to allow for multiple entry points. CO2 will be collected from various emitters such as coal fired power plants, upgrading/refining operations, petrochemicals and natural gas processing plants in and around Alberta's lndustrial Heartland. The CO2 will then be transported to aging reservoirs in southern Alberta for storage in EOR projects. The ACTL will be able to access reservoirs which are capable of storing over two billion tonnes of CO2, and producing an additional one billion barrels of high quality light crude oil using CO2 EOR. The ACTL will initially capture and store up to 1.6 million tonnes/year of CO2 from the Agrium fertilizer manufacturing facilities and North West Redwater Partnership Sturgeon Refinery (NWRPSR). At full capacity the ACTL project will store 14.6 million tonnes/year of CO2, the equivalent of removing 2.6 million cars from Alberta's roads, the ACTL project will be the word's largest Once fully operational CCS development.This paper will provide an update on the progress being made on the project as the ACTL has moved passed the regulatory phase and is now completing detailed engineering, with procurement underway. The ACTL has received regulatory approval for its pipeline construction and landowners along the entire pipeline route are supportive of the project. The presentation will address the project's development and stress the importance of the support from stakeholders. The paper will also outline the benefits of the project, and will explain how it balances environmental sustainability and economic viability while garnering public supportThe project is significantly advanced and is being financially supported by the Governments of Alberta and the Government Canada; the former through the Carbon Capture and Storage Program in the amount of $495MM CDN, and the latter through the ecoEnergy Technology Initiative and Clean Energy Fund in the amount of $63MM CDN. The estimated total cost of the full project is $1.15B CDN.Susan Cole will present the paper at the GHG-T 11 Conference. Susan is the founder and President of Enhance. Ms. Cole is a professional engineer with over 20 years of experience in the energy industry. Prior to founding Enhance, Ms. Cole was manager of the Weyburn CO2 Project in Saskatchewan, Canada, which is the largest industrial CO2 capture, transportation, and EOR/secure storage project in the world. She managed initial approval, facility construction and start-up phases of this project. As project manager she was responsible for the project implementation, including overall project coordination, economic modeling and start up. The Weyburn project is currently injecting over 6,000 tonnes of CO2 a day (or two million tonnes of CO2 a year) and is very similar in design and concept to the ACTL CCS-EOR project.

Commercial Structures for Integrated CCS-EOR Projects

In this paper, we evaluate alternate commercial structures for an integrated CCS-EOR project where the source of CO2 is a coal-fired power plant, and the CO2 is transported via a dedicated pipeline to an oil field where the CO2 is injected for EOR. We evaluate alternative contract types that link the involved entities in light of exogenous market risks, such as the fluctuating price of oil recovered. The choice of the contract type determines who would bear the risks along the value chain, and the incentives that the risk allocation produces fixes the total project value. We see that the fixed price contracts have weaknesses in terms of ex-post insolvencies and poor incentive structures that result in a sub-optimal decision-making by the involved entities. The risk-sharing offered by the indexed price contracts reduces the likelihood of ex-post insolvency and provides incentives to each entity to optimize the total project value. © 2010 Elsevier Ltd. All rights reserved