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Title: Impacts of Methane on Carbon Dioxide Storage in Brine Formations

 [1];  [2];  [2];  [2];  [3];  [4];  [3]; ORCiD logo
  1. School of Earth Sciences, The Ohio State University, Columbus OH, Department of Geology, University of Cincinnati, Cincinnati OH
  2. School of Earth Sciences, The Ohio State University, Columbus OH
  3. Biosciences Division, Oak Ridge National Laboratory, Oak Ridge TN
  4. The University of Tennessee, Knoxville TN
Publication Date:
Sponsoring Org.:
OSTI Identifier:
Grant/Contract Number:
Resource Type:
Journal Article: Publisher's Accepted Manuscript
Journal Name:
Ground Water
Additional Journal Information:
Related Information: CHORUS Timestamp: 2018-03-05 05:06:26; Journal ID: ISSN 0017-467X
Wiley - NGWA
Country of Publication:
United States

Citation Formats

Soltanian, Mohamad R., Amooie, Mohammad A., Cole, David R., Darrah, Thomas H., Graham, David E., Pfiffner, Susan M., Phelps, Tommy J., and Moortgat, Joachim. Impacts of Methane on Carbon Dioxide Storage in Brine Formations. United States: N. p., 2018. Web. doi:10.1111/gwat.12633.
Soltanian, Mohamad R., Amooie, Mohammad A., Cole, David R., Darrah, Thomas H., Graham, David E., Pfiffner, Susan M., Phelps, Tommy J., & Moortgat, Joachim. Impacts of Methane on Carbon Dioxide Storage in Brine Formations. United States. doi:10.1111/gwat.12633.
Soltanian, Mohamad R., Amooie, Mohammad A., Cole, David R., Darrah, Thomas H., Graham, David E., Pfiffner, Susan M., Phelps, Tommy J., and Moortgat, Joachim. 2018. "Impacts of Methane on Carbon Dioxide Storage in Brine Formations". United States. doi:10.1111/gwat.12633.
title = {Impacts of Methane on Carbon Dioxide Storage in Brine Formations},
author = {Soltanian, Mohamad R. and Amooie, Mohammad A. and Cole, David R. and Darrah, Thomas H. and Graham, David E. and Pfiffner, Susan M. and Phelps, Tommy J. and Moortgat, Joachim},
abstractNote = {},
doi = {10.1111/gwat.12633},
journal = {Ground Water},
number = ,
volume = ,
place = {United States},
year = 2018,
month = 1

Journal Article:
Free Publicly Available Full Text
This content will become publicly available on January 16, 2019
Publisher's Accepted Manuscript

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  • An important risk at CO2 storage sites is the potential for groundwater quality impacts. As part of a system to assess the potential for these impacts a geochemical scaling function has been developed, based on a detailed reactive transport model of CO2 and brine leakage into an unconfined, oxidizing carbonate aquifer. Stochastic simulations varying a number of geochemical parameters were used to generate a response surface predicting the volume of aquifer that would be impacted with respect to regulated contaminants. The brine was assumed to contain several trace metals and organic contaminants. Aquifer pH and TDS were influenced by CO2more » leakage, while trace metal concentrations were most influenced by the brine concentrations rather than adsorption or desorption on calcite. Organic plume sizes were found to be strongly influenced by biodegradation.« less
  • A laboratory-scale reactor was developed to evaluate the capture of carbon dioxide (CO{sub 2}) from a gas into a liquid as an approach to control greenhouse gases emitted from fixed sources. CO{sub 2} at 5-50% concentrations was passed through a gas-exchange membrane and transferred into liquid media - tap water or simulated brine. When using water, capture efficiencies exceeded 50% and could be enhanced by adding base (e.g., sodium hydroxide) or the combination of base and carbonic anhydrase, a catalyst that speeds the conversion of CO{sub 2} to carbonic acid. The transferred CO{sub 2} formed ions, such as bicarbonate ormore » carbonate, depending on the amount of base present. Adding precipitating cations, like Ca{sup ++}, produced insoluble carbonate salts. Simulated brine proved nearly as efficient as water in absorbing CO{sub 2}, with less than a 6% reduction in CO{sub 2} transferred. The CO{sub 2} either dissolved into the brine or formed a mixture of gas and ions. If the chemistry was favorable, carbonate precipitate spontaneously formed. Energy expenditure of pumping brine up and down from subterranean depths was modeled. We concluded that using brine in a gas-exchange membrane system for capturing CO{sub 2} from a gas stream to liquid is technically feasible and can be accomplished at a reasonable expenditure of energy. 24 refs., 9 figs., 2 tabs., 1 app.« less
  • Preliminary estimates of CO{sub 2} storage potential in geologic formations provide critical information related to Carbon Capture, Utilization, and Storage (CCUS) technologies to mitigate CO{sub 2} emissions. Currently multiple methods to estimate CO{sub 2} storage and multiple storage estimates for saline formations have been published, leading to potential uncertainty when comparing estimates from different studies. In this work, carbon dioxide storage estimates are compared by applying several commonly used methods to general saline formation data sets to assess the impact that the choice of method has on the results. Specifically, six CO{sub 2} storage methods were applied to thirteen salinemore » formation data sets which were based on formations across the United States with adaptations to provide the geologic inputs required by each method. Methods applied include those by (1) international efforts – the Carbon Sequestration Leadership Forum (Bachu et al., 2007); (2) United States government agencies – U.S. Department of Energy – National Energy Technology Laboratory (US-DOE-NETL, 2012) and United States Geological Survey (Brennan et al., 2010); and (3) the peer-reviewed scientific community – Szulczewski et al. (2012) and Zhou et al. (2008). A statistical analysis of the estimates generated by multiple methods revealed that assessments of CO{sub 2} storage potential made at the prospective level were often statistically indistinguishable from each other, implying that the differences in methodologies are small with respect to the uncertainties in the geologic properties of storage rock in the absence of detailed site-specific characterization.« less
  • This paper summarizes the results of a first-of-its-kind holistic, integrated economic analysis of the potential role of carbon dioxide (CO2) capture and storage (CCS) technologies across the regional segments of the United States of America (USA) electric power sector, over the time frame 2005-2045, in response to two hypothetical emissions control policies analyzed against two potential energy supply futures that include updated and substantially higher projected prices for natural gas. A key feature of this paper’s analysis is an attempt to explicitly model the inherent heterogeneities that exist in both the nation’s current and future electricity generation infrastructure and candidatemore » deep geologic CO2 storage formations. Overall, between 180 and 580 gigawatts (GW) of coal-fired integrated gasification combined cycle with CCS (IGCC+CCS) capacity is built by 2045 in these four scenarios, requiring between 12 and 41gigatons of CO2 (GtCO2) of storage in regional deep geologic reservoirs across the USA. Nearly all of this CO2 is from new IGCC+CCS systems, which start to deploy after 2025. Relatively little IGCC+CCS capacity is built before that time, primarily under unique niche opportunities. For the most part, CO2 emissions prices will likely need to be sustained at well over $10-20/ton CO2 before CCS begins to deploy on a large scale within the electric power sector. Within these broad national trends, a highly nuanced picture of CCS deployment across the USA emerges. Across the four scenarios studied here, some North American Electric Reliability Council (NERC) regions do not employ any CCS while others build more than 100 GW of CCS-enabled generation capacity. One region sees as much as 50% of their geologic CO2 storage reservoirs’ total theoretical capacity consumed by 2045, while the majority of the regions still have more than 90% of their potential storage capacity available to meet storage needs in the second half of the century and beyond.« less
  • This paper reports an experiment conducted on isothermal vapor-liquid equilibrium data for binary systems at high pressure. Carbon dioxide-methanol, carbon dioxide-ethanol, carbon dioxide-1-propanol, methane-ethanol, methane-1-propanol, ethane-ethanol, and ethane-1-propanol were measured by a new static phase equilibrium apparatus at 313.4 and 333,4 K.