The Sim-SEQ Project: Comparison of Selected Flow Models for the S-3 Site

Mukhopadhyay, Sudipta; Doughty, Christine; Bacon, Diana H.; Li, Jun; Wei, Lingli; Yamamoto, Hajime; Gasda, Sarah E.; Hosseini, Seyyed A.; Nicot, Jean‐Philippe; Birkhölzer, Jens

doi:10.1007/s11242-014-0361-0

Cited by 18 publications

(17 citation statements)

References 32 publications

(30 reference statements)

Supporting

Mentioning

Contrasting

Order By: Relevance

“…used high‐resolution characterization of CO 2 plumes using cross‐well seismic tomography, and reported a 30 m distance between F2 and F3. Similar distances were also used in the Sim‐SEQ project . Carrigan et al .…”

Section: Modeling Methods and Descriptionsupporting

confidence: 51%

“…Together, these simulation tools provided a more accurate match with both the observed pressure response and the CO 2 breakthrough times in two observation wells, F2 and F3, as compared to prior simulation studies for Cranfield. Earlier studies had mostly relied on upscaled petrophysical properties (e.g., permeability and porosity) and relatively coarse grids, and were conducted using, e.g., CMG, IPARS, iTOUGH2, TOUGH2/EOS7C, STOMP‐CO2e, TOUGH2‐MP/ECO2N, VESA, and MoReS . In Soltanian et al ., we also performed extensive parameter studies to investigate the relative importance of capillarity, Fickian diffusion, relative permeability, and sedimentary architecture (e.g., fluvial channel) effects and found that flow was highly advection dominated.…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Transport of perfluorocarbon tracers in the Cranfield Geological Carbon Sequestration Project

et al. 2018

View full text Add to dashboard Cite

A field‐scale carbon dioxide (CO2) injection pilot project was conducted by the Southeast Regional Carbon Sequestration Partnership (SECARB) at Cranfield, Mississippi. Two associated campaigns in 2009 and 2010 were carried out to co‐inject perfluorocarbon tracers (PFTs) and sulfur hexafluoride (SF6) with CO2. Tracers in gas samples from two observation wells were analyzed to construct breakthrough curves. In this work, we present the field data and numerical modeling of the flow and transport of CO2, brine, and tracers. A high‐resolution static model of the formation geology in the detailed area study (DAS) was used to capture the impact of connected flow pathways created by fluvial channels on breakthrough curves and breakthrough times of PFTs and SF6 tracers. We use the cubic‐plus‐association (CPA) equation of state, which takes into account the polar nature of water molecules, to describe the phase behavior of CO2–brine‐tracer mixtures. Our simulated results show good agreement for the 2009 tracer campaign in Cranfield, while a larger discrepancy emerges by 2010. The combination of multiple tracer injection pulses with detailed numerical simulations proves to be a powerful tool in constraining both formation properties and how complex flow paths develop over time. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

show abstract

Section: Modeling Methods and Descriptionsupporting

confidence: 51%

Section: Introductionmentioning

confidence: 99%

Transport of perfluorocarbon tracers in the Cranfield Geological Carbon Sequestration Project

et al. 2018

View full text Add to dashboard Cite

show abstract

“…Of the five teams reported in Mukhopadhyay et al . [] four used fully coupled three‐dimensional simulators and one team used a vertically integrated simulator. As would be expected, the discretization of the domain and representation of physical processes such as relative permeability varied widely among the different models.…”

Section: Practical Models and Their Applicationsmentioning

confidence: 99%

Status of CO₂storage in deep saline aquifers with emphasis on modeling approaches and practical simulations

et al. 2015

View full text Add to dashboard Cite

Carbon capture and storage (CCS) is the only viable technology to mitigate carbon emissions while allowing continued large-scale use of fossil fuels. The storage part of CCS involves injection of carbon dioxide, captured from large stationary sources, into deep geological formations. Deep saline aquifers have the largest identified storage potential, with estimated storage capacity sufficient to store emissions from large stationary sources for at least a century. This makes CCS a potentially important bridging technology in the transition to carbon-free energy sources. Injection of CO 2 into deep saline aquifers leads to a multicomponent, multiphase flow system, in which geomechanics, geochemistry, and nonisothermal effects may be important. While the general system can be highly complex and involve many coupled, nonlinear partial differential equations, the underlying physics can sometimes lead to important simplifications. For example, the large density difference between injected CO 2 and brine may lead to relatively fast buoyant segregation, making an assumption of vertical equilibrium reasonable. Such simplifying assumptions lead to a range of simplified governing equations whose solutions have provided significant practical insights into system behavior, including improved estimates of storage capacity, easy-to-compute estimates of CO 2 spatial migration and pressure response, and quantitative estimates of leakage risk. When these modeling studies are coupled with observations from well-characterized injection operations, understanding of the overall system behavior is enhanced significantly. This improved understanding shows that, while economic and policy challenges remain, CO 2 storage in deep saline aquifers appears to be a viable technology and can contribute substantially to climate change solutions.

show abstract

“…The original permeability and porosity distribution is from previously published studies . High permeability channels in the lower Tuscaloosa Formation at Cranfield have been mapped and confirmed by various fluid‐flow responses . However, the geometry of high permeability channels throughout the field is based on probabilistic extrapolation of the available data.…”

Section: Modeling Methods and Descriptionmentioning

confidence: 99%

Analysis of CO₂ storage mechanisms at a CO₂‐EOR site, Cranfield, Mississippi

et al. 2018

Self Cite

View full text Add to dashboard Cite

Carbon dioxide injected for enhanced oil recovery will partition into several phases in the target geological formation. The distribution into free or residually trapped oil, gas, and brine phases depends on many factors such as reservoir temperature and pressure, initial fluid saturations, brine salinity, and relative permeability parameters, and evolves through time including in the post‐injection period, during which it will tend to stabilize. Our numerical simulations, based on Cranfield, MS CO2‐EOR project data, demonstrate that these variations are significant and mostly dependent on the operator's selected field‐development strategy: continuous gas (CO2) injection, water alternating gas (WAG) injection, water curtain injection, or combinations thereof. In summary, our work shows that the field development strategy selected by the operator has a major impact on the relative importance of the different trapping mechanisms and that WAG seems to be a promising operational approach to balance both CO2 storage and oil production. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

show abstract

The Sim-SEQ Project: Comparison of Selected Flow Models for the S-3 Site

Cited by 18 publications

References 32 publications

Transport of perfluorocarbon tracers in the Cranfield Geological Carbon Sequestration Project

Transport of perfluorocarbon tracers in the Cranfield Geological Carbon Sequestration Project

Status of CO₂storage in deep saline aquifers with emphasis on modeling approaches and practical simulations

Analysis of CO₂ storage mechanisms at a CO₂‐EOR site, Cranfield, Mississippi

Contact Info

Product

Resources

About

The Sim-SEQ Project: Comparison of Selected Flow Models for the S-3 Site

Cited by 18 publications

References 32 publications

Transport of perfluorocarbon tracers in the Cranfield Geological Carbon Sequestration Project

Transport of perfluorocarbon tracers in the Cranfield Geological Carbon Sequestration Project

Status of CO2storage in deep saline aquifers with emphasis on modeling approaches and practical simulations

Analysis of CO2 storage mechanisms at a CO2‐EOR site, Cranfield, Mississippi

Contact Info

Product

Resources

About

Status of CO₂storage in deep saline aquifers with emphasis on modeling approaches and practical simulations

Analysis of CO₂ storage mechanisms at a CO₂‐EOR site, Cranfield, Mississippi