Cost Analysis of Carbon Capture and Sequestration from U.S. Natural Gas-Fired Power Plants.

Despite increasing efforts to decarbonize the power sector, the utilization of natural gas-fired power plants is anticipated to continue. This study models existing solvent-based carbon capture technologies on natural gas-fired power plants, using site-specific emissions and regionally defined cost parameters to calculate the cost of CO2 avoided for two scenarios: delivery to and injection within reliable sequestration sites, and delivery and injection for the purpose of CO2-enhanced oil recovery (EOR). Despite the application of credits from the existing federal tax code 45Q, a minimum incentive gap of roughly $38/tCO2 remains for the geologic sequestration of CO2 and $56/tCO2 for CO2-EOR (before consideration of revenue generated from delivered CO2 contracts). At full escalation of 45Q, delivered CO2 costs from this sector for geologic sequestration could reach as low as $22/tCO2. However, given the capital investment required in the near-term, it would be beneficial if the credit provided the greatest economic benefit early on and decreasing over time as deployment continues to ramp up. Additionally, due to the high qualifying limit of 45Q for the power sector, e.g., 500 ktCO2/yr, the tax credit incentivizes the capture of roughly 397 MtCO2/yr at a 90% capture efficiency or 75% of the emissions in this sector, with missed opportunities equating to roughly 118 MtCO2. Advancing the scale of carbon capture and sequestration (CCS) will require both technological advances in the capture technology, cost reductions through the leveraging of existing infrastructure, and increased policy incentives in terms of cost along with the reduction of qualifying limits.

Cost Analysis of Carbon Capture and Sequestration of Process Emissions from the U.S. Industrial Sector.

The industrial sector represents roughly 22% of U.S. emissions. Unlike emissions from fossil-fueled power plants, the carbon footprint of the industrial sector represents a complex mixture of stationary combustion and process emissions produced as a reaction byproduct of cement, iron and steel, glass, and oil production. This study quantifies the potential opportunities for low-cost carbon capture and storage (CCS) scenarios with process emissions from the U.S. industrial sector by analyzing the variabilities in point-source capture and geographic proximity to relevant sinks, specifically enhanced oil recovery (EOR) and geologic sequestration opportunities. Using a technology-agnostic cost model developed from mature CO2 capture technologies, costs of CCS are calculated for each of the 656 facilities considered, with application of the U.S. federal tax credit 45Q to qualifying facilities. Capture of these targeted industrial process emission streams may lead to the avoidance of roughly 195 MtCO2/yr (188 MtCO2/yr qualifying for 45Q). A total of 123 facilities have the potential to avoid roughly 68.5 MtCO2/yr at costs below $40/tCO2 delivered. This could be competitive for using CO2 for EOR depending on the price of oil. At regional CO2 collection hubs, emissions of 40 MtCO2/yr can be avoided within 100 miles of the existing Louisiana-Mississippi and Texas-New Mexico pipelines.

Cost Analysis of Direct Air Capture and Sequestration Coupled to Low-Carbon Thermal Energy in the United States.

Negative emissions technologies will play an important role in preventing 2 °C warming by 2100. The next decade is critical for technological innovation and deployment to meet mid-century carbon removal goals of 10-20 GtCO2/yr. Direct air capture (DAC) is positioned to play a critical role in carbon removal, yet remains under paced in deployment efforts, mainly because of high costs. This study outlines a roadmap for DAC cost reductions through the exploitation of low-temperature heat, recent U.S. policy drivers, and logical, regional end-use opportunities in the United States. Specifically, two scenarios are identified that allow for the production of compressed high-purity CO2 for costs ≤$300/tCO2, net delivered with an opportunity to scale to 19 MtCO2/yr. These scenarios use thermal energy from geothermal and nuclear power plants to produce steam and transport the purified CO2 via trucks to the nearest opportunity for direct use or subsurface permanent storage. Although some utilization pathways result in the re-emission of CO2 and cannot be considered true carbon removal, they would provide economic incentive to deploying DAC plants at scale by mid-century. In addition, the federal tax credit 45Q was applied for qualifying facilities (i.e., producing ≥100 ktCO2/yr).

Methane and CO2 Adsorption Capacities of Kerogen in the Eagle Ford Shale from Molecular Simulation.

Over the past decade, the United States has become a world leader in natural gas production, thanks in part to a large-fold increase in recovery from unconventional resources, i.e., shale rock and tight oil reservoirs. In an attempt to help mitigate climate change, these depleted formations are being considered for their long-term CO2 storage potential. Because of the variability in mineral and structural composition from one formation to the next (even within the same region), it is imperative to understand the adsorption behavior of CH4 and CO2 in the context of specific conditions and pore surface chemistry, i.e., relative total organic content (TOC), clay, and surface functionality. This study examines two Eagle Ford shale samples, both recovered from shale that was extracted at depths of approximately 3800 m and having low clay content (i.e., less than 5%) and similar mineral compositions but distinct TOCs (i.e., 2% and 5%, respectively). Experimentally validated models of kerogen were used to the estimate CH4 and CO2 adsorption capacities. The pore size distributions modeled were derived from low-pressure adsorption isotherm data using CO2 and N2 as probe gases for micropores and mesopores, respectively. Given the presence of water in these natural systems, the role of surface chemistry on modeled kerogen pore surfaces was investigated. Several functional groups associated with surface-dissociated water were considered. Pressure conditions from 10 to 50 bar were investigated using grand canonical Monte Carlo simulations along with typical outgassing temperatures used in many shale characterization and adsorption studies (i.e., 60 and 250 °C). Both CO2 and N2 were used as probe gases to determine the total pore volume available for gas adsorption spanning pore diameters ranging from 0.3 to 30 nm. The impacts of surface chemistry, outgassing temperature, and the inclusion of nanopores with diameters of less than 1.5 nm were determined for applications of CH4 and CO2 storage from samples of the gas-producing region of the Eagle Ford Shale. At 50 bar and temperatures of 60 and 250 °C, CH4 adsorption increased across all surface chemistries considered by 60% and 2-fold, respectively. In the case of CO2, the surface chemistry played a role at both 10 and 50 bar. For instance, at temperatures of 60 and 250 °C, CO2 adsorption increased across all surface chemistries by 6-fold and just over 2-fold, respectively. It was also found that at both 10 and 50 bar, if too low an outgassing temperature is used, this may lead to a 2-fold underestimation of gas in place. Finally, neglecting to include pores with diameters of less than 1.5 nm has the potential to underestimate pore volume by up to 28%. Taking into consideration these aspects of kerogen and shale characterization in general will lead to improvements in estimating the CH4 and CO2 storage potential of gas shales.

Carbon Capture and Utilization in the Industrial Sector.

The fabrication and manufacturing processes of industrial commodities such as iron, glass, and cement are carbon-intensive, accounting for 23% of global CO2 emissions. As a climate mitigation strategy, CO2 capture from flue gases of industrial processes-much like that of the power sector-has not experienced wide adoption given its high associated costs. However, some industrial processes with relatively high CO2 flue concentration may be viable candidates to cost-competitively supply CO2 for utilization purposes (e.g., polymer manufacturing, etc.). This work develops a methodology that determines the levelized cost ($/tCO2) of separating, compressing, and transporting carbon dioxide. A top-down model determines the cost of separating and compressing CO2 across 18 industrial processes. Further, the study calculates the cost of transporting CO2 via pipeline and tanker truck to appropriately paired sinks using a bottom-up cost model and geo-referencing approach. The results show that truck transportation is generally the low-cost alternative given the relatively small volumes (ca. 100 kt CO2/a). We apply our methodology to a regional case study in Pennsylvania, which shows steel and cement manufacturing paired to suitable sinks as having the lowest levelized cost of capture, compression, and transportation.

Effect of Ag and Pd promotion on CH4 selectivity in Fe(100) Fischer-Tröpsch catalysis.

The current CO2 utilization market is dominated by enhanced oil recovery and urea manufacturing; yet, the scale of demand falls well short of that deemed necessary to make a significant impact on climate change. CO2 conversion to fuels, however, is a utilization technology that can theoretically match the scale of projected CO2 capture. Fischer-Tröpsch (FT) processing is a long-established technology for converting non-petroleum based precursors into transportation fuels and other valuable chemicals. Here, we report the effects of Pd and Ag doping on CH4 selectivity over Fe(100), a common FT catalyst, as these metals have shown potential in the direct conversion of co-fed CO2. Adsorption energies for pathway specific C1 and C2 species were weakened in the presence of Ag and Pd by ca. 0.55 eV and 0.35 eV, respectively. Further, while both Ag- and Pd-promoted surfaces show decreased CH4 production, Ag introduces a prohibitively high coupling barrier; thus, only Pd offered a decrease in CH4 selectivity (-36%) relative to unmodified Fe(100).

Molecular simulations of nitrogen-doped hierarchical carbon adsorbents for post-combustion CO2 capture.

A present challenge in the mitigation of anthropogenic CO2 emissions involves the design of less energy- and water-intensive capture technologies. Sorbent-based capture represents a promising solution, as these materials have negligible water requirements and do not incur the heavy energy penalties associated with solvent regeneration. However, to be considered competitive with traditional technologies (i.e., MEA capture), these sorbents must exhibit a high CO2 loading capacity and high CO2/N2 selectivity. It has been reported that ultramicroporous character and surface nitrogen functionality are of great importance to the enhancement of CO2 capacity and CO2/N2 selectivity. However, the role of pore size in combination with surface functionality in the enhancement of these properties remains unclear. To investigate these effects, grand canonical Monte Carlo (GCMC) simulations were carried out on pure and N-functionalized 3-layer graphitic slit-pore models and compared to experimental results for two high performing materials reported elsewhere. We show that the quaternary, pyridinic, and especially the oxidized pyridinic group lend to enhanced performance, with the latter providing exceptional CO2 loading (4.31 mmol g-1) and CO2/N2 selectivity (138.3 : 1). Increasing surface nitrogen content resulted in enhanced loading and excellent CO2/N2 selectivity (45.8 : 1-55.9 : 1), provided that the sorbent has significant ultramicroporous character. Additionally, we elucidate a threshold pore width, under which N-functionalization becomes increasingly influential on performance parameters, and show how this threshold changes with application (PC vs. NGCC capture). Finally, we propose that an alternative functionality - the nitroso group - may be responsible for the enhanced performance of some recent materials reported in the literature.