Geochemical monitoring of fluid-rock interaction and CO2 storage at the Weyburn CO2-injection enhanced oil recovery site, Saskatchewan, Canada

Emberley, S.; Hutcheon, Ian; Shevalier, Maurice; Durocher, K.; Gunter, William D.; Perkins, Ernie

doi:10.1016/j.energy.2004.03.073

Cited by 136 publications

(50 citation statements)

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“…Injection of carbon dioxide in a structural trap is not required for containment: an open system can be used with the ultimate migration distance being limited by residual gas trapping and dissolution due to convective mixing. 5. In an open system, by the time all gas dissolves, migration can be up to tens of kilometres from the injection site.…”

Section: Discussionmentioning

confidence: 99%

“…The use of carbon dioxide in enhanced oil recovery (EOR) has been common since the 1980's, but until recently no consideration was given to CO 2 storage after the end of production. The Weyburn project 4 is a current example in the field of enhanced oil recovery that is accompanied by a monitoring program 5 to assess the location of the injected and stored carbon dioxide. Enhanced coal bed methane 6,7 and enhanced gas recovery [8][9][10] are also being investigated for feasibility.…”

Section: Introductionmentioning

confidence: 99%

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Role of Convective Mixing in the Long-Term Storage of Carbon Dioxide in Deep Saline Formations

Ennis‐King

Paterson

2003

SPE Annual Technical Conference and Exhibition

139

126

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractStorage of carbon dioxide in deep formations is being actively considered for the reduction of greenhouse gas emissions. Relevant experience in the petroleum industry comes from natural gas storage and enhanced recovery using carbon dioxide, but this experience is over a time scale less than the hundreds or thousands of years required for carbon dioxide storage. On these long time scales different mechanisms need to be considered.In the long-term the dominant mechanism for dissolution of carbon dioxide in formation water is convective mixing rather than pure diffusion. This arises because the density of formation water increases upon dissolution of carbon dioxide, creating a density instability. Linear stability analysis has been used to estimate the time required for this instability to occur in anisotropic systems. For sufficiently thick formations with moderate vertical permeability, this time is years to decades. Further approximate analysis shows that the time needed for the injected gas to dissolve completely is typically much longer, of the order of hundreds to thousands of years, depending on the vertical permeability. This theoretical analysis is found to be in broad agreement with the results of fine scale reservoir simulations. Laboratory experiments on an analogous system demonstrate the same phenomena.

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Section: Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Role of Convective Mixing in the Long-Term Storage of Carbon Dioxide in Deep Saline Formations

Ennis‐King

Paterson

2003

SPE Annual Technical Conference and Exhibition

139

126

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“…In particular, these analyses are critical for carbonate rocks, of which the permeability-porosity relations do not follow the trend observed in sandstones (e.g., Ehrenberg & Nadeau, 2005) due to more severe precipitation and (or) dissolution. From a practical perspective, the knowledge of diagenetic influences on k, especially those related to mineral precipitation and dissolution, could benefit many engineering projects such as geological CO 2 sequestration (Luquot & Gouze, 2009), bioremediation and soil improvement with microbially induced calcite precipitation (Achal et al, 2011;Montoya & DeJong, 2015), and oil recovery by injecting acid in reservoirs (Emberley et al, 2004).…”

Section: Introductionmentioning

confidence: 99%

Permeability Prediction in Rocks Experiencing Mineral Precipitation and Dissolution: A Numerical Study

Niu

Zhang

2019

Water Resources Research

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In this study, we focus on the electrical tortuosity‐based permeability model k = reff2/8F (reff is an effective pore size, and F is the formation factor) and analyze its applicability to rocks experiencing mineral precipitation and dissolution. Two limiting cases of advection‐dominated water‐rock reactions are simulated, that is, the reaction‐limited and transport‐limited cases. At the pore scale, the two precipitation/dissolution patterns are simulated with a geometrical model and a phenomenological model. The fluid and electric flows in the rocks are simulated by directly solving the linear Stokes equation and Laplace equation on the representative elementary volume of the samples. The numerical results show that evolutions of k and F differ significantly in the two limiting cases. In general, the reaction‐limited precipitation/dissolution would result in a smooth variation of k and F, which can be roughly modeled with a power function of porosity ϕ with a constant exponent. In contrast, the transport‐limited precipitation/dissolution mostly occurs near the pore throats where the fluid velocity is high. This induces a sharp change in k and F despite a minor variation in ϕ. The commonly used power laws with constant exponents are not able to describe such variations. The results also reveal that the electrical tortuosity‐based permeability prediction generally works well for rocks experiencing precipitation/dissolution if reff can be appropriately estimated, for example, with the electrical field normalized pore size Λ. The associated prediction errors are mainly due to the use of electrical tortuosity, which might be considerably larger than the true hydraulic tortuosity.

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“…As a matter of fact, upon injection, CO 2 can be dissolved in the formation water and produce carbonic acid, which significantly decreases the pH of the solution . Hence, faster chemical reactions enlarge pore spaces and reduce the strength of reservoir rocks . In the long term, these chemical interactions may result in reservoir compaction and wellbore integrity issues .…”

Section: Introductionmentioning

confidence: 99%

Impact of geochemical and geomechanical changes on CO₂ sequestration potential in sandstone and limestone aquifers

et al. 2019

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CO2 storage in different geological formations has been recognized as one of the promising mitigation approaches to reduce the emission of CO2 into the atmosphere. There are many complex hydro‐chemo‐mechanical interactions (effective stress changes, water acidification, and mineral dissolution) that may take place in a storage site during or after injection, reducing the integrity of formations in the short or long term. Although there have been several studies carried out in the past to assess the feasibility of sandstones and limestone formations as a safe CO2 storage site, the effect of hydrological, mechanical, and chemical processes on the storage site integrity has not been deeply addressed. The aim of this study is to couple thermo‐hydro‐chemo‐mechanical processes upon CO2 injection and assess their impact on the key storage aspects of quartz‐rich sandstone and calcite‐rich limestone. A numerical model was built to simulate CO2 flooding into a saline aquifer with sandstone and limestone composition for 500 years. The results obtained indicated that geochemical activity and CO2 dissolution are significantly higher in limestone and may increase the porosity by ∼16%. During injection, a decrease in the reservoir strength was observed in both rock types upon exposure to CO2. A remarkable variation in the geomechanical characteristics was also revealed in the sandstone after injection. However, ground displacements (subsidence) of 0.0017 and 0.033 m were, respectively, observed in sandstone and limestone aquifers, at the end of 500 years. It is recommended to consider a high‐strength reservoir for carbon capture and storage (CCS) projects in order to reduce the likelihood of compaction. It was also found that both rock types have a good storage capacity, injectivity, and trapping potentials (the structural and dissolution trappings) to capture and hold CO2 in place. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Geochemical monitoring of fluid-rock interaction and CO2 storage at the Weyburn CO2-injection enhanced oil recovery site, Saskatchewan, Canada

Cited by 136 publications

References 9 publications

Role of Convective Mixing in the Long-Term Storage of Carbon Dioxide in Deep Saline Formations

Role of Convective Mixing in the Long-Term Storage of Carbon Dioxide in Deep Saline Formations

Permeability Prediction in Rocks Experiencing Mineral Precipitation and Dissolution: A Numerical Study

Impact of geochemical and geomechanical changes on CO₂ sequestration potential in sandstone and limestone aquifers

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Geochemical monitoring of fluid-rock interaction and CO2 storage at the Weyburn CO2-injection enhanced oil recovery site, Saskatchewan, Canada

Cited by 136 publications

References 9 publications

Role of Convective Mixing in the Long-Term Storage of Carbon Dioxide in Deep Saline Formations

Role of Convective Mixing in the Long-Term Storage of Carbon Dioxide in Deep Saline Formations

Permeability Prediction in Rocks Experiencing Mineral Precipitation and Dissolution: A Numerical Study

Impact of geochemical and geomechanical changes on CO2 sequestration potential in sandstone and limestone aquifers

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Impact of geochemical and geomechanical changes on CO₂ sequestration potential in sandstone and limestone aquifers