This post was originally published on the Bureau of Economic Geology’s homepage.

Figure 1. (a and b) Direct pore-scale numerical simulations of two-phase flow in three-dimensional real-rock models using digital rock technology. (c and d, respectively) Invasion pattern of CO₂ injected into a water-wet and non-water-wet rock sample. CO₂ ganglia trapped in the pore space of (e) a water-wet sample and (f) a heterogeneous-wet sample.

When two fluids migrate together though pores in rocks, complex interactions occur between the fluids and with the rock matrix. These complexities influence the amount of each fluid that can be injected into or extracted from the pores, and how far fluids will migrate. Our team at the Gulf Coast Carbon Center studies the geosystem response to carbon dioxide (CO₂) injected into the subsurface to avoid emissions into the atmosphere—carbon storage. A major theme of our research is how to best design and monitor injection to maximize confidence in the ability of storage sites to retain CO₂ over periods of hundreds to thousands of years.

Buoyancy and viscous forces cause CO₂ to migrate away from the injection location, which increases the risk of its escape from the injection zone. We study the pore-scale processes that limit CO₂ plume migration and enhance storage capacity in saline aquifers. Two main processes effectively limit the plume extent: (1) capillary trapping, which happens when CO₂ pinches off and becomes immobilized in the pore space by capillary forces, and (2) dissolution trapping, where CO₂ gets dissolved and hence trapped in the resident brine. 

Traditionally, observations of pore-scale processes have been made using core samples in the laboratory. However, many factors limit this traditional approach, such as the cost and long time necessary for each analysis and the relative unavailability of high-quality cores. The core samples themselves have heterogeneous textures, which lead to various pore-scale responses of the fluids. Given these limitations, correct scaling of small-scale forces is difficult in the laboratory. In addition, the use of real fluid requires high pressure conditions and the use of proxy fluids is imprecise.

To resolve these issues, Sahar Bakhshian of the Gulf Coast Carbon Center spearheaded an innovation that creates pore-scale simulations of two-phase flow in real-rock models. By leveraging digital rock-scanning technology such as microtomographic imaging, our team can create a high-quality pore-scale model of any rock matrix. These high-resolution rock models allow many different numerical experiments to be run under controlled conditions. Exploiting parallel computing algorithms and high-performance computing platforms enables efficient computationally intensive simulations on high-resolution scanned rock images.

Using machine learning, our scientists aim to upscale these various pore-scale processes to determine how two-phase flow interacts at a large scale with bedforms, reservoir architecture, and basin-scale depositional systems to ensure responsible CO₂ injection and storage. Furthermore, we are advancing toward validating our numerical models using fabricated micromodels. With these innovations, we can better assess how much of the injected CO₂ will be retained near the injection well and how quickly and widely CO₂ will move underground using targeted study sites like the Miocene-aged sandstone strata of the subsea Gulf of Mexico. This information is needed to design commercial injection projects to reduce atmospheric CO₂ emissions.


Bakhshian, S., and Hosseini, S. A., 2019, Pore-scale analysis of supercritical CO₂-brine immiscible displacement under fractional-wettability conditions: Advances in Water Resources, v. 126, p. 96–107, doi:10.1016/j.advwatres.2019.02.008.

Bakhshian, S., Hosseini, S. A., and Lake, L. W., 2020, CO₂-brine relative permeability and capillary pressure of Tuscaloosa sandstone: effect of anisotropy: Advances in Water Resources, v. 135, no. 103464, 13 p., doi:10.1016/j.advwatres.2019.103464.

Bakhshian, S., Hosseini, S. A., and Shokri, N., 2019, Pore-scale characteristics of multiphase flow in heterogeneous porous media using the lattice Boltzmann method: Scientific Reports, v. 9, no. 3377, 13 p., doi:10.1038/s41598-019-39741-x.

Treviño, R. H., and Meckel, T. A., eds., 2017, Geological CO₂ Sequestration Atlas of Miocene Strata, Offshore Texas State Waters: The University of Texas at Austin, Bureau of Economic Geology Report of Investigations No. 283, 74 p.

Name of Project: Permanent Storage of CO₂—Contribution of Pore-Scale Modeling

Project PI: Sahar Bakhshian

Other key personnel: Tip Meckel, Susan Hovorka, Seyyed Hosseini, Ramón Treviño, Vanessa Nuñez-López, Alex Bump, Mike DeAngelo, Katherine Romanak, Dallas Dunlap, Iulia Olariu, Tucker Hentz, and students Melianna Ulfah, John Franey, Arnold Aluge, and Harry Hull

  • The International CCS Knowledge Centre has launched a new video series. The series, “Lead. Care. Adapt,” features 10-minute discussions with sustainability experts working to advance climate action including the role of carbon capture and storage (CCS) around the world.

    In the second video in the series, GCCC’s Katherine Romanak talks about the opportunities for CCS in developing countries and explains the support available to these regions to help move projects forward. Watch the video to learn what the Gulf Coast Carbon Center is doing to to lead, care, and adapt today for a better tomorrow.  

    View the feature here:

    Find the entire series here.

  • Summary: In 2018, the GCCC was awarded a large grant by the Department of Energy to study carbon capture and offshore storage in the western Gulf of Mexico. Together with partners in the eastern Gulf, the project leaders hosted their second annual partnership meeting entirely via webinar after travel plans to New Orleans were cancelled due to COVID-19.

    Recently, the Bureau of Economic Geology’s Gulf Coast Carbon Center (GCCC) joined the Southern States Energy Board (SSEB) for 2 days to conduct their annual joint partnership meeting—for the first time via webinar. Participants provided key updates on the research projects they lead on carbon capture and storage (CCS) in the Gulf of Mexico region.

    In 2018, the GCCC and the SSEB became principal investigators of two different multi-million-dollar projects funded by the Department of Energy (DOE) to explore carbon capture and offshore geological carbon storage in the subsurface under the U.S. Gulf of Mexico. The Gulf of Mexico Partnership for Offshore Carbon Storage (GoMCarb), led by the GCCC, explores the potential in the western Gulf region from western Louisiana to Texas. The second project, led by SSEB and called SECARB Offshore, explores the potential in the eastern Gulf region from eastern Louisiana to Florida.

    GoMCarb researchers gave updates throughout the first day on topics ranging from characterizing the subsurface geology of potential CO2 storage sites to transportation and infrastructure needs, risk assessment, subsurface monitoring, and stakeholder engagement in the GoMCarb project. GCCC members, including Susan Hovorka, Tip Meckel, Alex Bump, Sahar Bakhshian, Emily Moskal, Dallas Dunlap, and Iulia Olariu, gave presentations. Presentations were also given by partners at the U.S. Geological Survey, Lawrence Berkeley National Laboratory, Lawrence Livermore National Laboratory, Rice University, Lamar University, Total, Trimeric, and The University of Texas at Austin petroleum engineering, geophysics, and advertising departments.

    The SECARB Offshore and the GoMCarb projects advance and mature a series of offshore studies funded by the DOE. At the meeting, researchers presented maps of dozens of structurally defined fetch and trap areas with the potential to be developed as storage complexes. The internal sedimentary architecture of several areas shows favorable stacked traps and seals as well as defines the bounding faults. New work on infrastructure has advanced the potential for pipeline reuse, and, for the first time, risk-assessment work considered the impact and mitigation of offshore well blowouts that intersect stored CO2 plumes. The researchers are excited about the opportunities ahead for offshore CCS in the Gulf States, matched by the recent uptick in industry interest.

    The GoMCarb project runs through 2023. Each year, the GCCC and SSEB hold a joint partnership meeting to provide updates. For more details on the Gulf of Mexico Partnership for Offshore Carbon Storage, visit the project webpage.

    GoMCarb project works in the state waters off the coast of Texas and Louisiana

    This article originally appeared on the Bureau of Economic Geology’s homepage.