Bibliography - R. Bruant

1. Prévost, Jean H., R. Fuller, A. Altevogt, R. Bruant, and George Scherer, 2005: Numerical Modeling of Carbon Dioxide Injection and Transport in Deep Saline Aquifers. Proceedings of the 7th International Conference on Greenhouse Gas Control Technologies, (GHGT-7), http://www.princeton.edu/~cmi/research/Storage/Papers/NumericalModelingCarbonDioxide.pdf, 2189-2193
   [ Abstract ]

   We describe the development of a compositional resevoir simulator capable of modeling multiphase transport of CO₂ in a brine aquifer, and results are provided which illustrate the evolution of a 2-phase fluid system in which the injected CO₂ resides in a dense supercritical phase and also dissolves into the liquid phase. Salt precipitation into a solid phase is found to occur close to the injection well where the gas phase dominates.

2. Scherer, George, Michael Celia, Jean Hervé Prévost, , R. Bruant, A. Duguid, R. Fuller, S. Gasda, M. Radonjic, and W. Vichit-Vadakan, 2005: Leakage of CO₂ through Abandoned Wells: Role of Corrosion of Cement. The CO₂ Capture and Storage Project (CCP), Volume II, Chapter 10, 823-844
   [ Abstract ]

   The potential leakage of CO₂ from a geological storage site through existing wells represents a major concern. An analysis of well distribution in the Viking Formation in the Alberta basin, a mature sedimentary basin representative of North American basins, shows that a CO₂ plume and/or acidified brine may encounter up to several hundred wells. A review of the literature indicates that cement is not resistant to attack by acid, but little work has been reported for temperatures and pressures comparable to storage conditions. Therefore, an experimental program has been undertaken to determine the rate of corrosion and the changes in properties of oil well cements exposed to carbonated brine. Preliminary results indicate a very high rate of attack, so it is essential to have accurate models of the composition and pH of the brine, and the time that it will remain in contact with cement in abandoned wells. A model has been developed that incorporates a flash calculation of the phase distribution, along with analysis of the fluxes and pressure of the liquid, solid and vapor phases. A sample calculation indicates that wells surrounding the injection site may be in contact with the acidified brine for years.

3. Duguid, A., M. Radonjic, R. Bruant, T. Mandecki, George Scherer, and Michael Celia, 2004: The Effect of CO₂ Sequestration on Oil Well Cements. Proceedings of the 7th International Conference on Greenhouse Gas Control Technologies, (GHGT-7), http://www.princeton.edu/~cmi/research/Vancouver04/GHGT7Duguid.pdf,
   [ Abstract ]

   Experiments were conducted to examine the effects of CO₂ sequestration conditions on cements used to construct and abandon oil and gas wells. The results showed that significant damage, complete loss of the calcium hydroxide phase, can take place over a time span as short as seven days.

4. Bruant, R., D. E. Giammar, S.C.B. Myneni, and Catherine A. Peters, October 2002: Effect of pressure, temperature, and aqueous carbon dioxide concentration on mineral weathering as applied to geologic storage of carbon dioxide. Proceedings of the 6th International Conference on Greenhouse Gas Control Technologies (GHGT-6), http://www.princeton.edu/~cmi/research/kyoto02/bruant%20et%20al.kyoto%2002.pdf,
   [ Abstract ]

   CO₂ mediated dissolution of silicate minerals and subsequent precipitation of carbonates in deep saline aquifers may allow permanent trapping of carbon dioxide. However, the time-scales and extents of the reactions are poorly understood for CO₂ receptor formation conditions. To address these shortcomings, experiments were conducted to investigate the effects of pressure, temperature, and aqueous solution composition on rates and mechanisms of silicate mineral dissolution and carbonate precipitation. A high pressure/high temperature flow-through reactor system was used to derive steady-state dissolution rates of crushed forsteritic olivine. The system allowed continuous monitoring of temperature, pressure, and pH, and periodic sampling of effluent fluids for dissolved ion concentration analysis. Preliminary measurements of dissolution rates indicate good agreement with previously published measurements at ambient conditions. Increasing the pressure from 1 to 100 bar under constant CO₂ conditions increased the dissolution rate by ~80%. The same reactions were studied in batch systems using an array of analytical techniques to investigate dissolution mechanisms and secondary precipitate formation. The extent of olivine dissolution in the batch reactors increased with temperature, PCO₂, and surface area. Precipitation of magnesium-rich carbonates on reacted olivine was observed at initial magnesite saturation indices greater than 1.6.

5. Bruant, R., A. J. Guswa, Michael Celia, and Catherine A. Peters, 2002: Safe Storage of Carbon Dioxide in Deep Saline Aquifers. Environmental Science and Technology, 36(11), doi:10.1021/es0223325 240A-245A
   [ Abstract ]

   Over the past 420,000 years, global average atmospheric CO₂ concentrations have fluctuated narrowly between 180 and 280 parts per million by volume (ppmv), but since the Industrial Revolution, CO₂ concentrations have increased to ~370 ppmv. This increase is believed to be contributing to risingmean global temperatures (1, 2). Average annual global anthropogenic CO₂ emissions during the 1990s were ~27 GtCO₂/yr (1 GtCO₂ = 109 metric tons of CO₂ = 10¹² kg of CO₂ = 0.27 GtC). The Intergovernmental Panel on Climate Change estimates that under a “business-as- usual” energy scenario, global emissions will reach ~77 GtCO₂/yr by 2100, and the average atmospheric CO₂ concentration will reach ~750 ppmv (2). To stabilize atmospheric CO₂ concentrations at 550 ppmv, which is approximately twice preindustrial concentrations, global emissions must be continuously reduced so that by 2050, global emissions are 15 GtCO₂/yr less than the business-as-usual projection, and by 2100, emissions are 50 GtCO₂/yr less (2, 3).

6. Bruant, R., R. J. Held, Catherine A. Peters, and Michael Celia, 2001: Pore Scale Network Simulation of Single and Multiple Component Non-Aqueous Phase Luquid (NAPL) Dissolution. American Geophysical Union,
   [ Abstract ]

   A computational three-dimensional pore-scale network model was used to quantify residual single- and multi-component non-aqueous phase liquid (NAPL) dissolution driven by aqueous-phase advection. The pore network was discretized into spherical pore bodies and biconical pore throats to represent the effective void space and void distribution of a fine-grained Ottawa sand. Fluid saturations, positions, and interfacial areas, in addition to aqueous-phase flow, were established by externally applied pressure gradients. Mass transfer from the NAPL to the aqueous phase was computed as a local flux across each interface using a stagnant boundary layer Fickian diffusion model. Subsequent mass transport in the aqueous phase was simulated by a volume-conserving characteristic method along streamlines. The model dynamically calculated interface retraction resulting from mass transfer between the non-aqueous and aqueous phases, and concurrently tracked physical changes in NAPL saturation, NAPL composition, and interfacial geometry. The model avoids scale inconsistencies, allowing pore-scale through continuum-scale description of NAPL dissolution. In this presentation, results from NAPL dissolution simulations will be compared (as a function of saturation and location) to laboratory experiments and implications for up-scaling mass transfer coefficients will be discussed. Dependence of multi-component NAPL composition on mass transfer phenomena and differences between single- and multi-component systems also will be highlighted.

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