AusIMM’s Post

CO2 Sequestration [Trapping mechanisms; Over-lapping of time-scales] 1. How exactly to delineate the over-lapping of hydrodynamic trapping and capillary trapping with that of (a) Dissolution trapping (dissolution of scCO2 into brine across scCO2-brine interface)? (b) Mineral trapping (chemical reactions between rock-minerals and dissolved CO2, leading to the conversion of dissolved CO2 into solid-phase)? (c) Convection trapping (downward convective mixing of dissolved CO2 associated with the enhancement in brine density)? Or Whether, (a), (b) & (c) have completely different time-scales, which no more overlap with Hydrodynamic & Capillary trapping? Or Only (c) would remain to dominate, once the buoyant scCO2 plume reaches the top seal (leaving aside the mineral dissolution, which remains associated, only with, very large time levels)? Suresh Kumar Govindarajan https://lnkd.in/d6rtS6Ue https://lnkd.in/d_miY7ZU

CO2 Sequestration Diffusive Transport of CO2 Diffusion is the movement of CO2 molecules dissolved in brine solution from regions of high concentration to regions of low concentration, in the absence of bulk transport – governed by Fick’s law – which states that the diffusive flux remains proportional to the gradient of mass fraction of species, where the hydrodynamic dispersion coefficient plays the role of the proportionality coefficient. The diffusion of dissolved CO2 within brine solution depends on the effective diffusion coefficient for the dissolved CO2 in brine solution. How could we deduce the effective diffusion coefficient for the dissolved CO2 (only with brine saturation) in the absence of having data on accessible porosity, apparent diffusion coefficient, retardation factor and tortuosity factor? Suresh Kumar Govindarajan Professor (HAG)   IIT-Madras https://lnkd.in/d6rtS6Ue https://lnkd.in/d_miY7ZU 25-July-2024

Next in our series of technical notes is Modelling Migration of #CO2 in Fractures Basalt Reservoirs – Preliminary Testing of a Novel Multi-physics Reactive-Flow Model, by Marianne Nuzzo, Tiago Cunha, Shubhangi Gupta, Ewa Burwicz-Galerne and Christophe Galerne The geological storage of CO2 is a promising means to help reduce the emissions of greenhouse gases into the atmosphere during the energy transition stages (e.g., Raza et al., 2022). Carbon Capture and Storage (#CCS) is one of the essential technologies required to achieve global temperature rise limitations (IPCC, 2022) by contributing to the mitigation of carbon emissions from energy and industrial plants during the transition and is furthermore expected to support direct CO2 removal from the atmosphere on a longer timescale (Snaebjörnsdóttir et al., 2020). Storage of CO2 in geological formations depends on a combination of physical and chemical mechanisms such as physical trapping below caprocks or trapping by dissolution in groundwater. The most effective storage mechanism is the permanent mineralisation of CO2 by conversion into carbonate minerals (Benson et al., 2005). The relative trapping mechanisms contributions change through time after CO2 injection (Figure 1). Basalts have an excellent storage potential because they are widespread around the world and because the mineralisation of injected CO2 is completed within a decade or less, reducing leakage risks to a minimum (Oelkers et al., 2023). Please go to our website here https://lnkd.in/eN6hFUWU to read the rest of the technical note.

One of the goals of this paper was to provide an in-depth scientific analysis of a well-characterized natural Geological Hydrogen system so that it is possible to assess the feasibility of "stimulating" hydrogen production in the future through engineering approaches. Stimulating geological hydrogen to be economically feasible will be very challenging, requiring at least a 10,000 fold acceleration of the natural rate of hydrogen production for a low-temperature system. How might this be possible? It will require new technologies that can enable orders-of-magnitude changes in fracture density, chemical reaction rates and suppressed biological activity. There's rapid innovation occurring on these topics, which is exciting to see, so I'll also take this moment to say that tools and dedicated efforts to monitor the physical, chemical, and biological effects of stimulation are equally essential. We will need to thoroughly characterize and interpret how stimulation methods affect the subsurface system and the surrounding environment to ensure that geological hydrogen can be efficiently and safely produced.

Advanced Pulverized Coal Injection Technology and Blast Furnace Operation. In order to reduce the cost of running blast furnaces (BFs), injected pulverized coal is used rather than coke to fire BFs. As a result of this, unburned fine materials are blown with the gas into the bosh and dead man areas with possible detrimental effects on gas flow and permeability of the coke column. The capacity of the furnace to consume these particles by solution loss is probably one of the limitations to coal injection. The Committee of Pulverized Coal Combustion and In-Furnace Reaction in BF was set up in 1993 as a cooperative research of the Japan Society for the Promotion of Science (JSPS) and the Iron and Steel Institute (ISIJ) to evaluate research initiative into this problem. See following pictures for previously used standart coke furnace.

Academia and the autodidactic learners practicing their craft in industry need to form hyper-collaborative teams. We need to take the lessons learned from the computer chip industry and develop new technologies with everyone in the supply chain in alignment to benefit the end users and with “leaner + greener” solutions that will have less impact on our environment. If the only tool that you have is a hammer, every problem is a nail. If the only heat treating processes and equipment that you have in your captive heat treating department was designed in the last century, you can not possibly achieve “Grainular” consistency in your heat treated and forged products or utilize IHTS consultants’ suite of Quench2FIT Technologies to help eliminate post-heat treatment distortion and maintain higher levels of strength and ductility with the benefits of higher residual compressive surface stresses after tempering. See IHTS consultants “Resources” for more information on what we have developed for Heat Transfer Technologies.

* Investigation of carbide precipitates as hydrogen traps and their role in hydrogen embrittlement susceptibility of twinning-induced plasticity steel: https://lnkd.in/dJNswVpJ ABSTRACT: Solution and aging twinning-induced plasticity (TWIP) steel were obtained by the solution-treated at +1150°C for 2 h and aging-treated at +700°C for 6 and 24 h. Carbide precipitation is generated in the grain boundary and formed inside grains for aging time prolonging. Scanning Kelvin probe force microscopy was used to investigate the local distribution of hydrogen after hydrogen charging in TWIP steel with carbides in grain boundaries and grains. Results showed that carbides at the grain boundary adsorbed more hydrogen than those in the grain. Carbide precipitated phase as a hydrogen trap can enhance the resistance to hydrogen embrittlement and generated more secondary cracks at the grain boundary.

CO2 Sequestration [CO2-plume spread; viscous, gravity and capillary forces] To what extent, the aquifer/reservoir rock properties collected from the near-well region (through well-logging or coring); and the relative-permeability and capillary-pressure curves measured from laboratory using small rock samples, will remain to be useful in forecasting large-scale CO2 migration, where the CO2-plume could extend over hundreds of square kilometers, even before the injection period stops (10 -30 years)? And, how about the forecast of CO2-plume spread for the post-injection period that could span hundreds and thousands of years and longer? Having known that gravity and capillarity is expected to play a dominant role in dictating the flow behavior in the post-injection period, how long viscous forces would remain to be dominant during the injection period (in the vicinity of the injection well)? When exactly gravity and capillarity begin to influence the displacement front – during the injection period? Suresh Kumar Govindarajan https://lnkd.in/d6rtS6Ue https://lnkd.in/d_miY7ZU

CO2 Sequestration Henry’s Law When the quantum of the injected CO2 remains small, then, CO2 is completely dissolved in the brine solution, and this dissolved CO2 then migrates mainly by means of diffusion within the brine solution. If the aquifer remains characterized by low permeability, then, the process of dissolution of CO2 molecules in the brine solution of partially saturated aquifer material continues until the solubility limit of CO2 is reached – as described by Henry’s law (which states that the amount of gas that dissolves in a volume of liquid remains directly proportional to the partial pressure of dry CO2; and it depends on the mole fraction of dissolved CO2 in the brine solution). Can we expect the above scenario, in a deep saline aquifer with a low permeability?  OR Is it something to do 'only' with an unconfined aquifer - 'strictly' associated with the vadose zone? Suresh Kumar Govindarajan Professor (HAG)   IIT-Madras https://lnkd.in/d6rtS6Ue https://lnkd.in/d_miY7ZU 25-July-2024

𝗚𝗮𝘀 𝗱𝗲𝘁𝗲𝗰𝘁𝗶𝗼𝗻 𝗶𝗻 𝗺𝗶𝗻𝗲𝘀: 𝗻𝗲𝘄 𝘁𝗲𝗰𝗵𝗻𝗼𝗹𝗼𝗴𝗶𝗲𝘀 An intrinsically safe and explosion-proof dual-gas sensor system for the measurement of carbon monoxide (CO) and methane (CH4) was created in order to monitor gas explosion and coal spontaneous combustion in coal mines in an effective manner. This work was supported in part by the National Natural Science Foundation of China, the Changchun Key R&D Program, the Department of Education's Science and Technology Research Project, the Key R&D Program of Jilin Province, China, and the Program for JLU Science and Technology Innovative Research Team. Two measurement ranges of 0–500 ppmv and 0–300,000 ppmv for CH4 and 0–100 ppm and 0–4000 ppmv for CO were achieved using a ∼25 cm SPGC and a ∼25 m MPGC, respectively. At an averaging time of 0.5 s, the LoD is 0.19 ppmv for CO4 and 0.12 ppmv for CO, respectively. The T10%-90% and T90%-10% for the MPGC-based gas detection are ∼19 s and ∼26 s. For further reading: https://lnkd.in/e9gzRxzN Authors: Li, Y., Ma, Y., Zheng, C., Yu, D., Hu, L., Yang, S., Song, F., Li, Y., Liu, S., Zhang, Z., Zhang, Y., Wang, Y., & Tittel, F. K. (2024).