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Herein, a robust microporous aluminum tetracarboxylate framework, MIL‐120(Al)‐AP, (MIL, AP: Institute Lavoisier and Ambient Pressure synthesis, respectively) is reported, which exhibits high CO2 uptake (1.9 mmol g−1 at 0.1 bar, 298 K). In situ Synchrotron X‐ray diffraction measurements together with Monte Carlo simulations reveal that this structure offers a favorable CO2 capture configuration with the pores being decorated with a high density of µ2‐OH groups and accessible aromatic rings. Meanwhile, based on calculations and experimental evidence, moderate host‐guest interactions Qst (CO2) value of MIL‐120(Al)‐AP (−40 kJ mol−1) is deduced, suggesting a relatively low energy penalty for full regeneration. Moreover, an environmentally friendly ambient pressure green route, relying on inexpensive raw materials, is developed to prepare MIL‐120(Al)‐AP at the kilogram scale with a high yield while the Metal‐ Organic Framework (MOF) is further shaped with inorganic binders as millimeter‐sized mechanically stable beads. First evidences of its efficient CO2/N2 separation ability are validated by breakthrough experiments while operando IR experiments indicate a kinetically favorable CO2 adsorption over water. Finally, a techno‐economic analysis gives an estimated production cost of ≈ 13 $ kg−1, significantly lower than for other benchmark MOFs. These advancements make MIL‐120(Al)‐AP an excellent candidate as an adsorbent for industrial‐scale CO2 capture processes. [ABSTRACT FROM AUTHOR]

This study underscores the critical role of carbon capture and storage (CCS) in mitigating greenhouse gas emissions and addresses the potential for CCS projects in saline aquifers in Brazil, one of the world's largest carbon emitters. The country's ability to adopt CCS is significantly influenced by the availability of data related to regional CO2 storage potential and identifying suitable geological framework for CO2 injection. While oil and gas reservoirs have traditionally been prioritized, saline aquifers represent an underexplored and potentially higher capacity storage option. Despite Brazil's 31 sedimentary basins, the data quantity and availability for these contexts remain insufficient for advanced studies on the geological storage of CO2 considering saline aquifers. An initial study was conducted indicating five potential targets in the Paraná and Potiguar Basins for geological storage in saline aquifers based on available public data, mainly drilling data. This review reveals substantial challenges related to the evaluation of Brazil's CO2 storage capacity, such as the lack of modern seismic studies, the absence of a regulatory framework for CO2 storage, and insufficient investment in new well exploration. These challenges necessitate multistakeholder collaboration, the development of a supportive regulatory environment, and investment in extensive site characterization campaigns. Addressing these barriers is fundamental to realizing the country's CCS potential and contributing to global decarbonization efforts. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

With the increasing consumption of oil in the world and increasing production of oil from oil reservoirs, the reservoir pressure starts to decrease. On the other side, the use of oil leads to an increase in carbon dioxide production in the environment and causes global warming. One of the effective methods of reducing the amount of carbon dioxide emitted into the atmosphere and increasing the reservoir's pressure is CO2‐EOR and carbon capturing and storing (CCS) which injects produced carbon dioxide from industrial sources into underground reservoirs. Carbon dioxide reduces oil viscosity and increases oil mobility producing an economical state. Moreover, with CO2‐EOR and CCS carbon dioxide can be stored in a depleted reservoir and helps reduce pollution and global warming. Besides the environmental and economic benefits due to reducing carbon dioxide emissions to the atmosphere and increasing oil production, CO2 injection causes various problems in the formation. Many experiments indicate that asphaltene precipitation and wettability alteration caused by asphaltene, dissolution/precipitation of rock, salt precipitation, and sludge formation are some of the problems that occur during CO2 injection operations in low pressure and temperature. However, few experiments evaluate asphaltene precipitation effective factors, such as pressure, injection rates, temperature, etc., in high temperatures and pressure (HPHT) near reservoir conditions. Therefore, there was a need for a comprehensive investigation of various factors and the impact of each of them on the asphaltene precipitation and formation damage in HPHT conditions, so this research was designed to help future simulation and industrial utilization. A core‐flood setup was prepared to conduct CO2 flooding experiments and formation damage studies in HPHT conditions. The main objective of this study was to evaluate the effect of different parameters including pressure, injection rate, and type of injected gas on asphaltene and its effect on formation damage caused by CO2 injection. The second goal of this study was to investigate the optimum injection in every section. The third goal was to determine the oil recovery during the process of CO2 injection in different conditions. The results showed that an injection rate of 0.1 cc/min and higher injection pressures minimized asphaltene precipitation and maximized oil recovery. Replacing CO2 with natural gas liquids (NGL) gas reduced oil production and asphaltene precipitation. Overall, the experiments demonstrated the importance of optimizing injection parameters to limit formation damage during CO2 flooding. © 2024 The Authors. Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons Ltd. [ABSTRACT FROM AUTHOR]

Norway, a significant petroleum producer and exporter, has been a frontrunner within policies for carbon capture and storage (CCS). As CCS is recognized as a key technology for achieving the Paris climate policy targets, there is a clear need for more knowledge about how to design successful projects. Norway's first CCS policy initiative, the ambitious Mongstad project, was the result of a political compromise that was imposed from above, basically with one single company in control. The project was largely seen as a failure and was terminated in 2013. However, instead of dropping ambitions for developing CCS projects, the authorities launched a new policy soon afterwards. This policy evolved with the differently organized Longship CCS project as its core. Using a path‐dependency perspective, we find that established institutional structures from the Mongstad project, combined with national interests and expertise, help to explain the fundamental continuity of CCS policies in Norway. This explanation is supplemented by a policy‐learning perspective, which helps to explain policy changes and differences between the two flagship CCS projects. The Longship project developed gradually 'from below'; linked project responsibilities close to competences and interests; dealt with key risks separately to reduce the inherent complexity; and organized clear requirements up front. We hold that this way of designing CCS projects is of relevance to other countries considering CCS projects. Furthermore, by placing the Norwegian case in context of the development of EU and international climate policy we contribute a theoretical framework relevant also for subsequent research. [ABSTRACT FROM AUTHOR]

To‐date, only two UIC Class VI permits have been issued by the US Environmental Protection Agency. We illustrate a four‐phase workflow to first identify regional storage resources and then down‐select sites to yield permit‐ready locations that can accept and store large volumes of CO2. Specific permit requirements should guide objectives and define deliverables of respective workflow phases. In the first phase we used available regional data and screened structure and injection zones to locate resources that match CO2 volumes planned to be captured. Available data were also used to assess presence and depth of usable groundwater, the key resource being protected via permitting. We then used advanced, closed‐form, analytical solutions (EASiTool) to estimate CO2 injectivity into each hydrologically connected injection compartment. In the second phase we acquired and conditioned additional wireline logs and leased available seismic datasets. We interpreted the depositional systems from wireline well‐log character and mapped sandbody geometry to interpolate injection and confining‐zone distribution. Using available data, we mapped faults and locations of freshwater and overpressure (or other capacity‐limiting geologic parameters) in more detail. In the third phase, we used the augmented geologic data to develop a static model for the selected area, extracted the areas of highest interest, and generated and ran dynamic (flow) models. In a fourth phase, we reduced major uncertainties identified in earlier phases. Our case study indicates that to complete preparation of a permit application requires (1) improved lithologic characterization information (thicknesses and horizontal and vertical connectivity) and (2) better definition of poorly defined local faults. © 2023 The Authors. Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons Ltd. [ABSTRACT FROM AUTHOR]

In this study, ultra fine drop (<10pl) volume measurement technics were developed using chromatic confocal sensor(CCS). A printing pattern was printed on the substrate by printing equipment, and each sensor measures the height of the drop surface and by integrating them, the drop volume could be determined. To evaluate its performance, measurement accuracy, and the repeatability was determined. The measurement accuracy can be obtained by comparing the same drop volume measured by the confocal microscope. For the measurement repeatability, the same drop volume was measured for several times and its maximum and minimum value was used to determine. As a result, CCS showed a good measurement performance with measurement accuracy of more than 0.90 (R 2 in least square) and measurement repeatability of over 0.95. [ABSTRACT FROM AUTHOR]

Carbon capture and storage (CCS) has been highlighted as a crucial technology for reducing carbon emissions, yet CO₂ leakage from the reservoir is still a matter of great public concern, especially because of water pollution reasons. Hence, reduced‐scale CO₂ release experiments have been conducted worldwide to study hydrogeochemical response in shallow groundwaters. Although other reviews have been previously published, this study reviews critical data to establish a geochemical process‐based framework of the scientific findings. Following this, four mechanisms were found to be responsible for hydrogeochemical behavior: (i) ion exchange is mainly responsible for short‐lived increase in Mg, Ca, Ba and Sr concentrations; (ii) sorption and desorption processes were related to heavy metal and trace element variations, seemingly due to the presence of oxyhydroxides and clay minerals; (iii) silicate and carbonate dissolution played different roles as a function of specific aquifer mineralogy, releasing metals or influencing divalent cations response; (iv) conservative, mixing and oxidation processes were pointed out as possible mechanisms regulating variations of Cl⁻, SO₄2⁻ and NO₃⁻. Although studies suggested no parameter exceeded potable limits, most experiments were short‐lived, possibly overlooking the CO₂ leakage response in a long‐term exposure. Hence, further work is still needed specially to support relevant environmental legislation. © 2023 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

The Intergovernmental Panel on Climate Change concludes that CO2 capture and storage (CCS) is critical for climate‐stabilizing energy transitions. In CCS, captured CO2 is sequestered in saline aquifers within sedimentary basins. The CO2 storage capacity and the rate of injection are functions of the geology of the saline aquifer, which is uncertain. To minimize impacts of this uncertainty, CCS projects could include backup plans, such as co‐locating geologic CO2 storage (GCS) sites with or near existing CO2‐enhanced oil recovery (CO2‐EOR) operations. These "stacked storage" projects could hedge against uncertainty in the saline formation performance because captured CO2 could be injected into either location in the event of unexpected events (e.g., the injectivity decreases). Here, we investigate the possibility and ramifications of developing CCS networks in Oklahoma that are amendable to stacked storage. We find that stacked storage is possible in Oklahoma but the counties with the lowest‐cost saline storage resources do not have existing CO2‐EOR operations. At the systems level, we find it is slightly more expensive (e.g., $1/tCO2 to $5/tCO2) to site GCS in counties with CO2‐EOR projects. This increased expense is largely due to increased CO2 transportation costs because hundreds of km of additional pipeline is required to capture CO2 from the lowest‐cost sources. Overall, our results suggest that it is optimal to build more pipelines and avoid injecting CO2 in some of the lowest‐cost saline storage resources, to enable capturing CO2 from the least‐cost sources. © 2023 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Omics studies such as metabolomics, lipidomics, and proteomics have become important for understanding the mechanisms in living organisms. However, the compounds detected are structurally different and contain isomers, with each structure or isomer leading to a different result in terms of the role they play in the cell or tissue in the organism. Therefore, it is important to detect, characterize, and elucidate the structures of these compounds. Liquid chromatography and mass spectrometry have been utilized for decades in the structure elucidation of key compounds. While prediction models of parameters (such as retention time and fragmentation pattern) have also been developed for these separation techniques, they have some limitations. Moreover, ion mobility has become one of the most promising techniques to give a fingerprint to these compounds by determining their collision cross section (CCS) values, which reflect their shape and size. Obtaining accurate CCS enables its use as a filter for potential analyte structures. These CCS values can be measured experimentally using calibrant‐independent and calibrant‐dependent approaches. Identification of compounds based on experimental CCS values in untargeted analysis typically requires CCS references from standards, which are currently limited and, if available, would require a large amount of time for experimental measurements. Therefore, researchers use theoretical tools to predict CCS values for untargeted and targeted analysis. In this review, an overview of the different methods for the experimental and theoretical estimation of CCS values is given where theoretical prediction tools include computational and machine modeling type approaches. Moreover, the limitations of the current experimental and theoretical approaches and their potential mitigation methods were discussed. [ABSTRACT FROM AUTHOR]

The Autoclaved Aerated Concrete (AAC) industry has announced an ambitious decarbonization roadmap to 2050 to keep its place as a reference product in the future market of building materials. AAC raw materials are contributing to a large share of the CO2 footprint of AAC and need to be carefully assessed. Lime is today an essential raw material in the production of AAC and will remain so in the future as, unlike some other raw materials, it cannot be interchanged by a less carbon‐intensive alternative. Lime is essential in the formation of Tobermorite and provides the alkaline conditions required for the formation of the hydrogen bubbles structuring the mineral foam. Lime is produced by the calcination of limestone (CaCO3) releasing carbon dioxide (CO2). The CO2 footprint of lime is considerable, and the production process is considered hard‐to‐abate. Today roughly two‐thirds of the CO2 is inherent to the production process while only one‐third of the CO2 is due to the required fuel. Lhoist has developed a Carbon Action 2030 plan with a range of low‐carbon and carbon‐neutral lime solutions. The approach is based on the principle of three pillars: Avoiding, Reducing, and Compensating with a pipeline of effective carbon reduction initiatives behind each pillar. The paper will provide a status update on the key projects in Belgium, France, and Germany. The transformation to low‐carbon lime has triggered projects in energy improvement, sustainable fuels, the usage of hydrogen, kiln electrification, oxyfuel kilns, carbon capture, and storage as well as CO2 utilization. Once the CO2 is captured during the production of lime, the carbonation of the AAC will lead to a carbon‐negative building material. Our roadmap will position Lhoist as a preferred partner for the AAC industry in the future. Our lime product portfolio ranging from Level|Blue™ to Level|Green™ will support the AAC industry to consolidate and develop its referential position in the building materials industry. [ABSTRACT FROM AUTHOR]

Carbon dioxide capture and geologic storage (CCS; geologic sequestration) is a promising technology for reducing anthropogenic greenhouse gas emissions to the atmosphere from industrial point sources. Aspects of CCS have been investigated for over two decades, and many large‐ and small‐scale geologic storage field demonstration projects are now underway globally. Interest in offshore CCS has been increasing in recent years (e.g., European Union, Australia, Japan, and the United States). Deep geologic storage in offshore settings is analogous to onshore CCS activities in many respects (i.e., geologic and geotechnical aspects), but is distinct from previously explored seabed sediment CO2 storage) or deep marine dissolution). Given the large subsurface geologic storage volumes available in offshore settings, much discussion of offshore CCS is focused on the benefits and risks of such activity compared to onshore settings. Similar to onshore settings, existing (legacy) wells likely present the most direct migration pathway and largest risk of noncontainment in offshore settings. As part of current studies to evaluate geologic storage options in offshore settings along the Texas coast and greater Gulf of Mexico (GoM), mapping of the geographic distribution and ages of wells in a region containing coastal counties and extending 30 miles offshore Texas indicates that both well spatial density and well age decrease moving from onshore to offshore. Results suggest reduced risk of leakage owing to more rigorous and documented well completion and abandonment practices for these generally younger wells (although many are decades old). A result of decreased well density is that larger areas are available for leasing for CCS projects that avoid legacy wells altogether (> 1 mile from any existing well). The one‐mile designation is used as an arbitrary convention, and while it is recognized that this is smaller than a typical area of review (AoR) for permitting, each site will have a different AoR radius for consideration. The combination of large subsurface storage volumes under control of a single landowner and reduced risks from legacy wells makes offshore CCS attractive in the GoM. © 2023 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

The presence of carbon capture and storage (CCS) projects is important due to the growing production of greenhouse gases, especially carbon dioxide (CO2). Our target functions have been chosen because of the importance of CO2 storage in CCS projects and the requirement for producing less water in projects requiring water production. As a proxy for reservoir simulations, support vector regression, artificial neural network (ANN), and multivariate adaptive regression spline (MARS) have been used. It was determined that MARS had higher accuracy based on examining these three data‐driven models with the available field data. It was, however, very close to the accuracy of the ANN. MARS gave root mean square of error (RMSE), mean absolute error (MAE), and R2 values of 2.78%, 1.95%, and 0.998, respectively, for predicting CO2 storage values in test data, yet 3.73%, 3.53%, and 0.995 for blind data. The RMSE, MAE, and R2 to evaluate the machine learning (ML) model for predicting water production were 3.58%, 2.81%, and 0.997, respectively, while the results for blind data were 3.94%, 2.83%, and 0.997, respectively. By reducing the amount of computational load and time taken to reproduce the simulation data by MARS, it will be beneficial for optimization. This study highlights the application of the ML approach to coupling with genetic algorithms and optimizing CO2 storage and water production. With the proposed frameworks, preprocessing, feature selection, two‐stage validation of the data‐driven model, and optimizer are performed in the aquifer and a repository containing a series of optimal solutions is developed to be used in projects. [ABSTRACT FROM AUTHOR]

Carbon capture and storage (CCS) plays an important role in promoting developing countries to reduce carbon emission and meet the requirement for carbon reduction under carbon neutral and carbon peak targets. To evaluate the incentive effect of subsidization mechanisms on CCS investment, the paper incorporates two incentives into the model, considers the effects of the carbon trading price, electricity price, and other uncertain factors on the investment behaviors for CCS projects under uncertainty and explores incentive intensity of two policies on investment based on the real option method. The results show that even in the case of full operating cost subsidies and double electricity price subsidies, the power plant still delays CCS investment due to the imperfection of carbon market. The most appropriate policies for supporting immediate investment in CCS project are identified in the paper by considering the critical carbon price and electricity price in different scenarios. Additionally, the findings show that it is more efficient for the electricity price subsidy than cost subsidy with same subsidy proportion under single policy condition, while the minimum subsidy amount required to invest immediately is 32.86 million CNY in the combination of the two policies. This provides environmental policymakers with valuable insights on promoting CCS deployment under the context of carbon reduction. © 2022 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Researchers worldwide are taking advantage of novel, commercially available, technologies, such as ion mobility mass spectrometry (IM‐MS), for metabolomics and lipidomics applications in a variety of fields including life, biomedical, and food sciences. IM‐MS provides three main technical advantages over traditional LC‐MS workflows. Firstly, in addition to mass, IM‐MS allows collision cross‐section values to be measured for metabolites and lipids, a physicochemical identifier related to the chemical shape of an analyte that increases the confidence of identification. Second, IM‐MS increases peak capacity and the signal‐to‐noise, improving fingerprinting as well as quantification, and better defining the spatial localization of metabolites and lipids in biological and food samples. Third, IM‐MS can be coupled with various fragmentation modes, adding new tools to improve structural characterization and molecular annotation. Here, we review the state‐of‐the‐art in IM‐MS technologies and approaches utilized to support metabolomics and lipidomics applications and we assess the challenges and opportunities in this growing field. [ABSTRACT FROM AUTHOR]

This paper is written in response to the paper "How green is blue hydrogen?" by R. W. Howarth and M. Z. Jacobson. It aims at highlighting and discussing the method and assumptions of that paper, and thereby providing a more balanced perspective on blue hydrogen, which is in line with current best available practices and future plant specifications aiming at low CO2 emissions. More specifically, in this paper, we show that: (i) the simplified method that Howarth and Jacobson used to compute the energy balance of blue hydrogen plants leads to significant overestimation of CO2 emissions and natural gas (NG) consumption and (ii) the assumed methane leakage rate is at the high end of the estimated emissions from current NG production in the United States and cannot be considered representative of all‐NG and blue hydrogen value chains globally. By starting from the detailed and rigorously calculated mass and energy balances of two blue hydrogen plants in the literature, we show the impact that methane leakage rate has on the equivalent CO2 emissions of blue hydrogen. On the basis of our analysis, we show that it is possible for blue hydrogen to have significantly lower equivalent CO2 emissions than the direct use of NG, provided that hydrogen production processes and CO2 capture technologies are implemented that ensure a high CO2 capture rate, preferably above 90%, and a low‐emission NG supply chain. [ABSTRACT FROM AUTHOR]

In order to achieve greenhouse gas neutrality, hydrogen generated from renewable sources will play an important role. Additionally, as underlined in the Sixth Assessment Report of the Intergovernmental Panel on Climate Change (IPCC), new technologies to remove greenhouse gases from the atmosphere are required on a large scale. A novel concept for hydrogen production with net negative emissions referred to as HyBECCS (Hydrogen Bioenergy with Carbon Capture and Storage) combines these two purposes in one technological approach. The HyBECCS concept combines biohydrogen production from biomass with the capture and storage of biogenic carbon dioxide. Various technology combinations of HyBECCS processes are possible, whose ecological effects and economic viability need to be analyzed in order to provide a basis for comparison and decision‐making. This paper presents fundamentals for the techno‐economic and environmental evaluation of HyBECCS approaches. Transferable frameworks on system boundaries as well as emission, cost, and revenue streams are defined and specifics for the application of existing assessment methods are elaborated. In addition, peculiarities concerning the HyBECCS approach with respect to political regulatory measures and interrelationships between economics and ecology are outlined. Based on these considerations, two key performance indicators (KPIs) are established, referred to as levelized cost of carbon‐negative hydrogen (LCCNH) and of negative emissions (LCNE). Both KPIs allow deciding whether a specific HyBECCS project is economically viable and allows its comparison with different hydrogen, energy provision, or negative emission technologies (NETs). Carbon‐negative hydrogen production referred to as HyBECCS (Hydrogen Bioenergy with Carbon Capture and Storage) combines hydrogen production from biomass with the capture and storage of biogenic carbon dioxide. Various technology combinations of HyBECCS processes are possible, whose ecological effects and economic viability need to be analysed. This paper presents fundamentals for the techno‐economic and environmental evaluation of HyBECCS approaches. Transferable frameworks on system boundaries as well as emission, cost and revenue streams are defined and specifics for the application of existing assessment methods are elaborated. [ABSTRACT FROM AUTHOR]

District heating (DH) systems can improve energy efficiency, reduce greenhouse gas (GHG) emissions, and be a cost‐effective residential space heating alternative over conventional decentralized heating. This study uses radiative forcing (RF), a time‐sensitive life cycle assessment metric, to evaluate space heating alternatives. We compare forest residue and willow biomass resources and natural gas as fuel sources against decentralized heating using heating oil. The comparison is performed for selected locations in the Northeastern United States over a 30‐year production timeline and 100 observation years. The natural gas and willow scenarios are compared with scenarios where available forest residue is unused and adds a penalty of GHG emissions due to microbial decay. When forest residues are available, their use is recommended before considering willow production. Investment in bioenergy‐based DH with carbon capture and storage and natural‐gas‐based DH with carbon capture and storage (CCS) technology is considered to assess their influence on RF. Its implementation further improves the net carbon mitigation potential of DH despite the carbon and energy cost of CCS infrastructure. Soil carbon sequestration from willow production reduces RF overall, specifically when grown on land converted from cropland to pasture, hay, and grassland. The study places initial GHG emissions spikes from infrastructure and land‐use change into a temporal framework and shows a payback within the first 5 years of operation for DH with forest residues and willow. [ABSTRACT FROM AUTHOR]

An intermediate‐scale beadpack drainage experiment was conducted to investigate how simple layered lamination heterogeneity affects CO2 flow. Two simple layers of capillary barriers are manually packed in the tank and slow drainage was carried out using analog fluids to mimic the capillary‐ and gravity‐dominated CO2 upward migration process in deep saline aquifers. Nonwetting phase saturation time series clustering analysis and frequency analysis have been conducted on the experimental data. Additionally, modified invasion percolation numerical simulations were done on a digital model of the beadpack to compare to experimental results. Results show that capillary barriers can lead to strong pulsation behavior, which in turn can cause unexpected early breaching through other barriers. The inlet pressure is found to be able to respond to saturation changes in far regions of the domain, indicating that the wetting phase can transmit pressure changes from the other phase. Although static simulations were not able to capture all the dynamic behavior observed in the experiment, Monte Carlo composite simulation results combining many different realizations can better illustrate how the nonwetting phase will behave in the heterogeneous domain. Our results suggest the need for CO2 storage site selection with preference given to aquifers with more capillary barriers with finer grain sizes to avoid flow pulsation and to retard plume upward migration. Key Points: Conducted a low‐rate buoyancy‐driven drainage experiment in a dm‐scale beadpack and simulations to study nonwetting phase pulsationFlow pulsation can cause nonwetting phase fluids such as CO2 to breach the capillary barriers before bypassing themModified invasion percolation probabilistic simulations can satisfactorily match dynamic experimental fluid flow results [ABSTRACT FROM AUTHOR]

Container‐based virtualization is becoming increasingly popular in the cloud industry, as it provides services to the client as per their requirements. Requirements of the user can be described in a configuration file. Cloud provider offers the services to the client using "pay‐as‐you go" model. Docker provides support to a cloud provider for the creation of a container, deployment of the container, and monitoring of services running inside a container on the host and guest system both. The creation and deployment of the container by Docker efficiently is a big challenge. In this paper, we capture the behavior of the container life cycle through process algebra (CCS) and properties of it as a formula using μ‐calculus. Further we capture the behavior of deployment of the container on the host machine through CCS and its properties through the model μ‐ calculus. We used model checking tool Concurrency Workbench of the New Century to verify the creation of the Docker container as well as deployment of it. [ABSTRACT FROM AUTHOR]

This paper presents a workflow for delineating a risk‐based area of review (AOR) to support a US Environmental Protection Agency (EPA) Class VI permit for a carbon dioxide (CO2) storage project. The approach combines semianalytical solutions for estimating formation fluid leakage through a hypothetical leaky wellbore with the results of physics‐based numerical reservoir simulations. The workflow is demonstrated using a case study for a hypothetical 180,000‐metric‐ton‐per‐year storage project located in the Plains CO2 Reduction (PCOR) Partnership region, which includes all or part of 10 states in the United States and four Canadian provinces. Under the scenario where the leaky wellbore is open to a saline aquifer (thief zone) between the overlying seal (cap rock) and the underground sources of drinking water (USDW), the risk‐based AOR is no larger than the areal extent of the CO2 plume in the storage reservoir because the pressure buildup in the storage reservoir beyond the CO2 plume is insufficient to drive formation fluids up a hypothetical leaky wellbore into the USDW. However, even under the conservative assumption that the leaky wellbore is not open to a thief zone, the incremental leakage beyond the areal extent of the CO2 plume is less than 400 m3 over 20 years. The approach outlined in this paper is designed to be protective of USDWs and comply with the Safe Drinking Water Act requirements and provisions for the EPA Class VI Underground Injection Control (UIC) Program (Class VI Rule) and North Dakota Administrative Code Chapter 43‐05‐01. © 2021 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

The Gulf Coast of the United States hosts diverse power generation, refining, and petrochemical processing facilities, resulting in the nation's largest volumetric concentration of industrial CO2 emissions, rivaled only by the Ohio River Valley. These emissions sources are concentrated in specific industrial clusters that allow combining emissions streams to achieve economies of scale. The region is currently undergoing globally significant industrial expansion and investment as a result of abundant and inexpensive regional unconventional natural gas availability, and is a growing exporter of liquefied natural gas (LNG). Opportunities to integrate CO2 emission management within the diverse energy chains in the region are volumetrically significant and include both concentrated and dilute sources. Significant examples of capture, transport, and storage exist. Offshore storage is particularly attractive, as it provides simplified land leasing models (single governmental land owner), proven reservoir quality, and presents fewer risks to both protected groundwater and populated areas. Projects can now take advantage of recently expanded opportunities under section 45Q of the Internal Revenue Service tax code. The region continues to evolve as an active carbon‐handling hub, and is uniquely suited to justify additional investment in carbon capture, utilization, and storage (CCUS) technologies via a large‐scale integrated project development. Continued development of integrated projects will allow the region to continue to grow economically within its strong fossil‐fuel handling competence focus while advancing low‐carbon energy technologies that maintain globally competitiveness. © 2021 The Authors. Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons Ltd. [ABSTRACT FROM AUTHOR]

Upscaling Carbon Capture and Storage requires identification of suitable storage sites, with robust reservoir seals. The Utsira Formation in the northern North Sea has been flagged as a target for further storage. However, there are no regional studies of seal variability addressing heterogeneities that could facilitate seal bypass. This study aims to: (a) identify, assess and map the elements that promote or restrict fluid migration, (b) develop a matrix to regionally map containment confidence (CC) and (c) rank the different areas for CO2 containment across the Utsira Formation. The seal and overburden were mapped using a high‐resolution, pre‐stack depth‐migrated 3D broadband seismic reflection dataset and 141 exploration wells. Seal geometry, sandstone presence and sandstone connectivity in the seal and overburden were assigned relative CC scores, which were summed to map overall CC of the Utsira Fm. Indicators for shallow gas and migration were mapped and correlated with the other elements. Areas with the lowest CC are in the west of the Utsira Fm. Here, sandstones within the Seal Interval are connected through the overburden via sandy submarine fans. In the southeast, dipping stratigraphy downlaps onto the Utsira Fm., increasing the potential for connection with glacially‐derived channel‐lobe systems in the overburden. The areas with the highest CC are the central and northeast parts of the Utsira Fm., where the Seal Interval is mudstone‐dominated and parallel to the reservoir, and channel‐lobe systems identified in the Overburden Interval are disconnected from the reservoir. This area coincides with a thick depocentre of the northern Utsira Fm. These results can be used to inform CO2 storage site selection and constrain future CO2 plume simulation analyses for the Utsira Fm. The CC matrix outlined here can also be adapted and applied to regionally assess the containment of other potential CO2 storage reservoirs in any setting. [ABSTRACT FROM AUTHOR]

The impact of fines migration on fracture transmissivity reduction was investigated by injecting a brine solution containing a suspension of 0.1 wt.% kaolinite particles with a mean particle size distribution of 9.6 μm through fractured shale core samples. The fractures had apertures estimated to be approximately 100 μm. A mass balance approach was used to determine the quantity of kaolinite that was deposited within the fractures (influent – effluent = amount deposited in fractures). Large fractions (44–90%) of the suspended kaolinite pumped through the fractures were deposited within the fractures. Based on fracture volumes estimated with X‐ray computed tomography, it was determined that approximately 10 to 17% of the fracture volume was filled with kaolinite at the point when flow was completely restricted. These results indicate that 100 μm fractures in CO2 reservoir caprocks could be sealed within hours if the brines passing through the fractures contain a proportional volume of particulates to the tests performed in this laboratory study. © 2021 Battelle Memorial Institute. Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons Ltd. [ABSTRACT FROM AUTHOR]

Injectivity index is a powerful tool that can be easily calculated from field injection and pressure data. Theoretically, injectivity index is linked to reservoir properties such as permeability, thickness of pay, and size of the reservoir. Consequently, injectivity index data can serve as a powerful tool to assess changes in reservoir quality and performance. In this article, we have looked at field data from notable global carbon sequestration projects in order to identify a correlation between injectivity index (J) and the product of reservoir permeability and thickness (kh). Results suggested that there is a linear relationship between J and kh with field data confirming to lower and upper bounds of J = 0.03×kh and J = 0.23×kh respectively. Average trend was calculated to be J = 0.08×kh. This correlative approach can be extremely beneficial when there is a need to estimate pressure buildup corresponding to a target injection or vice versa. The approach can also be used to understand reservoir flowability and performance at a broader scale prior to the need for expensive or time consuming flow and pressure transient testing. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

One of the most promising, cost‐effective, and readily available technologies for reducing greenhouse gas emissions to the atmosphere is the capture and separation of CO2 from large stationary sources and storage in geological formations. Storage security, especially in the early stages of operation, is mostly guaranteed by caprock formations with very low permeability overlying the reservoir, capable of containing the injected fluid. Chemical alterations of the formation brine, caused by CO2 injection may cause dissolution and precipitation of secondary minerals, potentially increasing the risks of leakage from the reservoir. In order to evaluate these processes and their potential to induce the formation of leakage pathways in ultrafine fault gouges, a series of batch experiments was performed on crushed and sheared samples from three different caprock formations from Northern Europe (Sollingen, Röt and Opalinus claystones). The experiments were supported by numerical models of the kinetics of mineral dissolution and precipitation simulating the same experimental conditions, and over a longer time (10 000 years). Minor mineral alterations were observed after the batch experiments, the most important being: illite dissolution for the Opalinus and Röt formation samples, and dolomite dissolution and the transformation of illite and chlorite into kaolinite for the Sollingen sample. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

The targets of limiting global warming levels below 2°C or even 1.5°C set by Paris Agreement heavily rely on bioenergy with carbon capture and storage (BECCS), which can remove carbon dioxide in the atmosphere and achieve net zero greenhouse gas (GHG) emission. Biomass and coal co‐firing with CCS is one of BECCS technologies, as well as a pathway to achieve low carbon transformation and upgrading through retrofitting coal power plants. However, few studies have considered co‐firing ratio of biomass to coal based on each specific coal power plant's characteristic information such as location, installed capacity, resources allocation, and logistic transportation. Therefore, there is a need to understand whether it is worth retrofitting any individual coal power plant for the benefit of GHG emission reduction. It is also important to understand which power plant is suitable for retrofit and the associated co‐firing ratio. In order to fulfill this gap, this paper develops a framework to solve these questions, which mainly include three steps. First, biomass resources are assessed at 1 km spatial resolution with the help of the Geography Information Science method. Second, by setting biomass collection points and linear program model, resource allocation and supply chain for each power plants are complete. Third, is by assessing the life‐cycle emission for each power plant. In this study, Hubei Province in China is taken as the research area and study case. The main conclusions are as follows: (a) biomass co‐firing ratio for each CCS coal power plant to achieve carbon neutral is between 40% and 50%; (b) lower co‐firing ratio sometimes may obtain better carbon emission reduction benefits; (c) even the same installed capacity power plants should consider differentiated retrofit strategy according to their own characteristic. Based on the results and analysis above, retrofit suggestions for each power plant are made in the discussion. [ABSTRACT FROM AUTHOR]

New challenges regarding system stability and efficiency arise when power systems operate with a high penetration level of inverter‐based renewable sources (IBRSs) and few synchronous generators. Since IBRSs have been on the rise, to secure the stable operation of future power systems, IBRSs will be required to support systems without having to rely on remaining synchronous generators. Also, to efficiently manage the uncertainty of renewable production, power‐to‐gas technology can provide the required flexibility. This study proposes modelling and a control coordination scheme (CCS) of a wind‐to‐hydrogen (W2H) set to optimise electricity production from a variable‐speed wind turbine generator (WTG) while helping balance between supply and demand in a system. To achieve this, a grid‐forming (GFM) inverter‐based WTG is modelled and a set of electrolyser and fuel cell is integrated at the DC circuit of a GFM‐WTG to be coordinated. Furthermore, the CCS offers an opportunity to reduce the investment cost for deploying a W2H set by utilising the control capabilities of a WTG and reducing the need for an additional device. The performance of the proposed W2H set with the CCS was verified considering the variations in system load and wind speed by using Power System Computer Aided Design (PSCAD)/ElectroMagnetic Transients including Direct Current (EMTDC). [ABSTRACT FROM AUTHOR]

Increasing greenhouse gas emissions and negative environmental consequences have raised worldwide attention to ecological issues. The development of carbon regulations (CRs) beside carbon capture and storage (CCS) systems is part of carbon mitigation policies (CMPs), which are following in recent years to control and manage carbon liberation. Along with environemtal policies, the utilization of renewable energy resources have been promoted significantly. However, the economic opportunities for renewable energy development considering CMPs have not addressed extensively. In this study, a stochastic mathematical programming model has been presented to minimize cost and downside risk (DSR) of the bioelectricity generation supply chain considering the pre‐ and postdisaster conditions. The role of several CMPs on the economic behavior of the system has been analyzed by investigating the potential uncertainties on material availability, material quality, and consumer demand. To consider disruption effects, the postdisaster stage has been classified into several substages including damage, recovery, and back to the sustainability stages. Mississippi State after the Katrina Hurricane is addressed as a case study to examine the performance of the proposed model. The results demonstrated that the occurrence of disruptive uncertainties creates 8,978,502 $, 8,864,335 $ and 8,884,055 $ as the DSR, under carbon tax policy (CTP), carbon offset policy (COP), and CCS, respectively. The effect of disruptive scenario 1 with a 15% reduction of resource has led to the greatest postdisaster supply chain costs in comparison with other scenarios. Although the financial analysis showed CTP has the greatest DSR after the occurrence of disaster, this policy has the most investment attractions, as well as COP, with the internal rate of return (IRR) of 9%. While implementing the CCS policy with the IRR of 2% creates 7% missed opportunity costs compared with other CMPs. [ABSTRACT FROM AUTHOR]

With the aim of using side‐scan sonar (SSS) in marine monitoring at offshore CO2 storage sites, an experiment was conducted in a bay with a flat seabed, approximately 32 m deep. CO2 bubbles released at regulated rates between 500 and 5000 mL min−1 were searched for with SSS to elucidate the detection limit, which depends on the towing speed and the altitude of SSS, and the horizontal distance between the release point and SSS. When the towing speed was less than 6 knots, SSS was able to detect CO2 bubbles released at 1000 mL min−1 (approximately 4 tonnes year−1), which is an extremely small rate compared with injection rates in commercial scale storage, O(106) tonnes year−1. The time required for searching an area of 1 km2 with SSS was estimated to be between 1.7 and 3.4 hours, assuming that SSS was towed at an altitude of 27 m. Thus, SSS was demonstrated to be serviceable for marine monitoring. pH measured at 5 m away from the release point dropped by larger than 0.05 four times during the experiment. Only one of them might have been due to the CO2 release, and the others were due to intrusion of water from deeper layers because temperature, salinity and dissolved oxygen simultaneously changed. This indicates that bubble searching with SSS could detect smaller‐scale CO2 leakages than locating anomalous carbonate values, although the latter is still important in case all or most of CO2 dissolve before the emission to the sea. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

CO2 storage projects are financially intensive and, without the European Union emission trading scheme that encourages CO2 emission reduction projects, they will not be cost effective, that is, feasible. Similar to the huge uncertainties involved in long‐term energy price prediction, CO2 market price is volatile. In this paper, indicators for key CO2 price changes are detected by moving average analysis. To prove the validity of the methods, geometric Brownian motion (GBM) simulations were performed for different drift and volatility values. Drift, the standard deviation of CO2 price changes and CO2 volatility were used on a daily, weekly and monthly basis for short term simulations and on a weekly basis for long term simulations. GBM simulation can help determine the probability of a European emission allowances (EUA) price, which is featured by great variations, depending on the period. Signals for periods were determined by momentum strategy, with 60 days for short and 365 days for the long moving average. They show correlation with natural gas prices, that is, EUA signals appear 13–17 months after the signal in natural gas price. Among the vast number of proposed hybrid prediction models, this correlation allows the prediction of a long‐term price trend. It seems that back‐loading measures obstructed risk estimates because they resulted in extreme price drift in some periods, as the consequence of rebalancing in supply and demand. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Heat storage (HS) instalment in combined heat and power (CHP) plants is a promising solution to increase the adjustability of CHP plants and reduce renewable energy curtailment. Despite the proposed optimisation models and algorithms, it still lacks a dispatching framework for HS facilities to integrate with the existing dispatching system of power grids. This study integrates a coordination control system (CCS) and a plant‐level energy management system (PEMS) into the existing dispatching system and proposes the corresponding scheduling method to ensure the rationality, veracity, and timeliness of scheduling. The CCS generates power and thermal generation schedules in multi‐time scales, while the PEMS operates as the bridge between the HS facilities and the CCS. Meanwhile, taking into account the actual scheduling requirements, the authors propose a downward spinning reserve capacity (DSRC) preservation method for the dispatch of CHP plants, develop multi‐level coordination and progressive refinement strategy for schedules and apply the DSRC as a criterion to obtain the day‐ahead, the rolling and the real‐time schedules in sequence. Finally, the dispatch simulation results show that the newly proposed CHP dispatching framework can schedule the HS facilities in CHP plants effectively and achieve the desired effect of wind power accommodation. [ABSTRACT FROM AUTHOR]

Introduction: Plant medicine/herbal extracts are typically complex, encompassing a wide range of flavonoid diversity and biological benefits. Combined with a lack of standards; species authentication profiling is a challenge. A non‐targeted screening strategy using two‐dimensional (2D) separation and specificity of ultra‐high‐performance liquid chromatography ion mobility collision‐induced dissociation mass spectrometry (UHPLC‐IM‐CID‐MS) has been investigated, to identify the 6‐C and 8‐C‐glycosylflavone isomer orientin/isoorientin and vitexin/isovitexin pairs in Passiflora species. Utilising available standards and "known–unknowns" a reference CCS (collision cross‐section) speciation finger print for Passiflora extracts could be generated to illustrate species profiling. Material and Methods: SPE was performed to extract flavonoids of interest from powdered and ground Passiflora leaf. Chromatographic separation was achieved via UHPLC and analysis performed using positive/negative ion electrospray coupled with linear T‐wave IM‐MS (calibrated to perform accurate mass and CCS measurements). Results: Comparative phytochemical screening of Passiflora alata, P. edulis, P. incarnata and P. caerulea leaf extracts has generated CCS, CID IM product ion spectra, 2D separation with UHPLC‐IM‐MS, enabling the unequivocal identification of flavone C‐glycosides in complex extracts. A phytochemical reference CCS library was generated comprised of "knowns" and "known–unknowns". Isomers have been differentiated using a CCS metric enabling novel CCS specific isomeric quantitation of co‐eluting isomers. Conclusions: The screening approach illustrated has the potential to play an important role in the profiling of medicinal plants to determine phytochemical make‐up and improve consumer safety through generation of highly specific speciation profiles. Natural product plant matrices are typically complex, encompassing a wide range of flavonoid diversity. Passiflora leaf extracts have been analysed using UHPLC‐IM‐MS 2D separation and specificity. CCS values have been determined to differentiate isomeric marker critical pairs. Chromatographically coeluting isomeric product ion spectra have been deconvoluted. In addition cumulative specificity incorporating CCS has been used to produce a highly specific "known‐unkown" speciation fingerprint and the combination of CCS with 2D separation has enabled novel isomeric quantitation. [ABSTRACT FROM AUTHOR]

Injecting supercritical CO2 into the subsurface changes the temperature, pressure, and geochemistry of the storage reservoir. Understanding these perturbations within the reservoir may be used to monitor the CO2 plume during a carbon capture and sequestration (CCS) project. Here we analyze results from 1‐D, 2‐D, and 3‐D numerical modeling studies to investigate how the thermal signature of the CO2‐water system evolves during CCS. These models show that the thermodynamic processes of the CO2‐water system results in a characteristic thermal profile within a homogeneous storage reservoir during a CO2 injection. This thermal signature is characterized by warming front of up to 4 °C, which is caused by CO2 dissolution and migrates contemporaneously with free‐phase CO2 migration. When reservoir properties are highly heterogeneous, this thermal front travels well ahead of free‐phase CO2, thus implying that thermal monitoring may be an effective predictor of CO2 breakthrough. Plain Language Summary: When CO2 is injected into a geologic reservoir, it causes the pressure, temperature, and chemical systems with the reservoir to change. Understanding these changes are important in order to plan a CO2 injection and monitor the CO2 during the injection. Monitoring CO2 in the subsurface is required to avoid negative health, safety, and environmental impacts. The temperature effects associated with a CO2 injection may be used as a way to monitor the CO2 plume during the injection phase. Results here show that the heat of dissolution can cause temperature to increase up to 4 °C and can be used as a way to predict the arrival of CO2. Key Points: Thermodynamic processes induce warming of 1‐4 °C at the leading edge of a CO2 plumeHeat and CO2 migrate contemporaneously within homogeneous reservoirsPositive thermal anomalies migrate weeks to years ahead of free‐phase CO2 in heterogeneous reservoirs [ABSTRACT FROM AUTHOR]

Carbon capture and storage (CCS) is an important low‐carbon management technology used to reduce CO2 emissions with the captured anthropogenic CO2 for enhanced oil recovery (EOR). This paper provides an overview and analysis of current issues related to CCS projects and CCS technologies. The paper also assesses risks and costs as well as policy, legal, and regulatory frameworks relevant for CCS and the major countries with CCS deployment. Currently, the few CCS projects in operation are mostly for EOR purposes. However, miscible CO2‐EOR in depleted oil and gas reservoirs appears to be the industry's first choice for CO2 sequestration and increasing oil production. Potential CO2 leakage is a major risk for pipelines and geological storage and a comprehensive monitoring program needs to be developed to ascertain its impact on pipeline material integrity, humans, and the environment. The cost of the CCS chain largely depends on the compression solvent for the synthesis gas or flue gas treatment for separation, heat rate, energy required for capture, capital costs of capture equipment, pipeline diameter, and flow capacity, and the homogeneity and permeability of the geological formations. An effective carbon pricing and cap‐and‐trade system as a part of national carbon policy is needed to achieve the goal of CCS. This paper finally discusses China's carbon capture utilization and storage (CCUS) systems and proposes a new CCUS‐LNG transportation process system for the coastal areas of China. Special attention was focused on CO2 transportation, CCUS‐EOR, and a new CCUS‐LNG process system for China. [ABSTRACT FROM AUTHOR]

Carbon capture and storage (CCS) has been proposed as a bridging technology to enable the transition to an energy system based on renewable sources. Many high CO2‐emitting industries (such as the power industry) are distant from potential carbon storage sites (such as offshore geological reservoirs) and an infrastructure of CO2 transportation must therefore be developed to carry the CO2 to safe storage. As such there is a need to understand the risks involved and the mitigation of potential leaks associated with CCS and dense‐phase CO2 transportation networks. Since 2012 a number of experimental studies have provided a mechanistic understanding of the risks posed to crops as a function of CO2 leakage from CCS infrastructure. However, what remains largely unresolved is the role played by both soil type and soil structure in mitigating and / or enhancing plant stresses. In this study we provide an experimental framework to evaluate these effects. Wheat and beetroot were grown in four different experimental soils to test the effects of specific soil attributes (organic, low pH; organic, open structure; organic, limed; loam, neutral pH) on crop performance when exposed to high levels (∼40%) of CO2 in the soil environment. Comparison between treatment and controls and across the soil types reveals little difference in terms of biomass or plant stress chemistry. From a stakeholder perspective these findings suggest that soil type may play only a minor role in mitigating or amplifying plant stress in response to the unlikely event of a CO2 leak from CCS infrastructure. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Potential CO2 leakage from carbon capture and storage (CCS) facilities should be monitored and managed carefully. Biomonitoring technologies for CO2 leakage using plants could be very effective, especially in areas near transport pipelines, because of the extensive areas that they can cover. A greenhouse study was conducted to investigate whether early changes in plant parameters could be an effective indicator to detect leaked CO2. Corn (Zea mays), which was reported to be a CO2‐tolerant species, was selected to identify specific indicators of CO2 leakage. The mean soil CO2 concentration for soil treated with CO2 was 20–40%, which is similar to the concentration that could occur near transport pipelines through slow‐insidious seepage. In the soil treated with CO2, the number of yellow leaves at the canopy level was significantly increased from the sixth day of CO2 injection compared to the control. The chlorophyll content in green leaves was significantly reduced on the eighth day from CO2 injection. The soil water content in the treated soil was increased from the sixth day of injection due to reduced root adsorption. The results of this study implied that early changes in parameters of CO2‐tolerant species such as canopy‐level discoloration and chlorophyll content could be used as CO2‐specific indicators for the detection of soil CO2 leakage. We suggested that canopy‐level monitoring is a promising, useful technique for soil CO2 leakage in extensive areas, such as near CO2 transport pipelines. In addition, rhizosphere‐level parameters, such as soil water content, could be good subsidiary indicators together with the large‐scale collection of baseline data and statistical analysis. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

To identify risks, project teams may envision scenarios that involve specific project components or activities. But have all the important risks been identified? This is the Achilles' heel of risk identification. An important risk might be overlooked and thus be left unaddressed. Many risk‐identification schemes fail to target consciously risk sources that lie in the gaps among the scheme's components or outside the scheme altogether. The Whole Story framework suggested here is comprehensive in that (1) each of its six independent perspectives is nominally holistic on its own, and (2) the perspectives themselves overlap. This minimizes the conceptual space where undetected risks can hide. The core of the Whole Story framework is journalistic: ask who, what, when, where, why, and how. Each query becomes an independent project breakdown system: a project is viewed as the sum of its actors (who), and as the sum of its functional components (what), and as the sum of its phases (when), etc. Risks are then identified with respect to each element of each system. Each system views the project from a different angle, so risks hidden among the elements of one system may be revealed through other systems' perspectives. Extra diligence in risk identification can be far less costly than data gaps or hardware retrofits caused by nontreatment of an overlooked risk. In this article, the six project breakdown systems are tailored to CO2 capture and geologic storage (CCS) projects but, because the six journalistic queries are universally applicable, the Whole Story framework can be adapted to leading‐edge projects of many types. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Abstract: Carbon capture and geological storage are among the most valuable technologies capable of reducing CO2 emissions. Long‐term interactions between CO2 and a reservoir, and the integrity of geological formations, are key factors in the selection of adequate reservoirs for permanent storage. Numerical models of CO2‐water‐rock geochemical interactions are often employed to predict the fate of CO2 stored in a reservoir over time. The Hygiene Sandstone, in the Denver Basin, Colorado, USA, is a geological formation with potential for CO2 storage, and was therefore studied in this work, in which we collected and characterized outcrop samples in order to supply the input parameters for numerical simulations. Four representative thin sections of Hygiene Sandstone outcrops were quantified in terms of detrital constituents, diagenesis, and porosity on the basis of conventional petrography. Sandstone mineralogy included, in decreasing order, quartz, K‐feldspar, muscovite, albite, illite, smectite, kaolinite, poikilotopic calcite, and siderite. Porosity ranged from 4% to 13%. A geochemical modeling study of CO2‐water‐rock interactions performed with two characterized samples and brine data from the Hygiene Sandstones, simulating reservoir conditions, suggested that the mineralogy of the sandstone is quite stable under the conditions that were tested and only minor mineralogical and porosity alterations would occur within a thousand years of storage. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Abstract: Carbon dioxide capture and storage (CCS) is an effective technology to reduce carbon dioxide (CO2) emissions in China. In this paper, the authors considered storage opportunities offered by oil reservoirs and deep saline aquifers in the Jiyang Depression, in east China. Based on detailed geological analysis and assessment of CO2 storage suitability, the Dongying Sag and Linyi‐Shanghe areas of the Huimin Sag within the Jiyang Depression appear promising for CO2 storage. Following more detailed characterization, the second and third members of the Shahejie Formation located in these two areas appear the most promising for CO2 storage. Within the areas identified as having potential for storage, 55 primary and 62 secondary recommended storage units were defined, with a total theoretical capacity of 5.02 × 108 tonnes (t) CO2. This represents storage of CO2 emissions from large‐scale sources in the Jiyang Depression for more than 30 years at current emission rates. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Abstract: In this paper, the optimal investment timing decision in carbon capture and storage (CCS) is studied under different business modes. Two analytical models of the optimal CCS investment threshold are presented: one is the ‘single mode,’ meaning that CCS investment is performed only by the power producer; the other is the ‘cooperation mode,’ referring to CCS investment can be conducted by cooperation between the power producer and the CCS operator. In the single mode, this study pictures the investment decision for a CCS project based on real options theory considering uncertainties in carbon prices, government incentives, and CCS investment costs. On this basis, a model for the cooperation mode is proposed by integrating real options theory and game theory to analyze the CCS investment threshold. The results of a numerical example show that CCS investment in cooperation mode requires a much larger threshold than in single mode. Moreover, the CCS investment threshold is positively affected by carbon price volatility and the transfer payments coefficients, but negatively affected by government incentives and learning effects. These conclusions provide a theoretical foundation for decision making regarding CCS investment and related policy making. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Exergy and exergoeconomic analyses have been used to set out weaknesses of the postcombustion CO2 capture unit of Besat power plant that uses an ammonia absorption refrigeration system for CO2 liquefaction. The energy required for the absorption system is provided by the flue gas. The liquefied CO2 is used for beverage and food industries. The exergoeconomic costs of all utility streams and processes are calculated through a systematic method of assigning exergetic cost relations to the streams. The results point out that the exergy destruction of the CO2 stripper and absorber columns are the highest, and according to the cost‐based information, potential locations for the process improvement are proposed. A comprehensive method based on thermodynamic and mathematical methods has been proposed to acquire efficient design parameters and consumed power in compressors. It is based on a combination of Aspen HYSYS® and MATLAB® to do calculations and then an optimization procedure based on genetic algorithms. Results show that the production cost of each ton CO2 is equal to 6.05 (USD/ton) and return on investment can also be obtained by 2.5 years considering USD 1,600,000 of annual revenue. © 2018 American Institute of Chemical Engineers Environ Prog, 37: 1075–1084, 2018 [ABSTRACT FROM AUTHOR]

The technology of circulating fluidized beds (CFBs) is applied to temperature swing adsorption (TSA) processes for post‐combustion CO2 capture employing a commercial zeolite sorbent. Steady state operation is simulated through a one‐dimensional model, which combines binary adsorption with the CFB dynamics. Both single step and multi‐step arrangements are investigated. Extensive sensitivity analyses are performed varying the operating conditions, in order to assess the influence of the main operational parameters. The results reveal a neat superiority of multi‐step configurations over the standard one, in terms of both separation performance and efficiency. Compared to fixed‐bed TSA systems, CFB TSA features a high compactness degree. However, product purity levels are limited compared to the best performing fixed‐bed processes, and heat management within the system appears to be a major issue. As regards energy efficiency, CFB systems place themselves in between the most established absorption‐based technologies and the fixed‐bed TSA. © 2017 The Authors AIChE Journal published by Wiley Periodicals, Inc. on behalf of American Institute of Chemical Engineers AIChE J, 64: 1744–1759, 2018 [ABSTRACT FROM AUTHOR]

In this study, an improved phase current control scheme (CCS) for switched reluctance generator is developed and evaluated. The objective of proposed CCS is to find the most efficient operating point according to output power command directly and shorten the online tuning process. The CCS is augmented with an online phase current distributing block (OCDB) and a dynamic firing angle regulator (DFAR). In OCDB, phase current is distributed online to minimise copper loss by maximising the average‐torque–ampere ratio. In DFAR, firing angles are processed according to actual phase current and current command. Improvements in current responses by augmenting DFAR are verified by simulations and experiments. In the end, the proposed CCS is employed in an output power controller for practical applications. Experimental results show that the proposed CCS has good dynamic response and finds the most efficient operating point directly. [ABSTRACT FROM AUTHOR]

Abstract: Carbon dioxide capture is regarded as an effective method of greenhouse gas reduction. Post‐combustion capture from power plants will play a key role in CO2 abatement due to their important contribution to total CO2 emissions. Compared with the state‐of‐the‐art amine scrubbing technology, adsorption‐based post‐combustion capture (PCC) possesses excellent potential for lowering energy demand, and thus the total cost. Due to their relatively weak interaction with CO2, carbons showed lower adsorption capacity during PCC as compared with some benchmark materials (e.g. amine‐based adsorbents); however, their high cyclic stability and fast adsorption/desorption kinetics suggest that carbons have the important potential to achieve an optimized or balanced performance, and thus provide a low‐cost PCC process. In this review, we present preparation options and consider the structure‐performance relationship in CO2 capture with carbons, and summarize recent progress on using carbons for CO2 capture with special focus on PCC. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

CO2 sequestration into saline aquifers is considered to be one of the most promising options for reducing industrial CO2 emissions to the atmosphere. However, there are still many uncertainties regarding the storage of CO2 in the subsurface because of a lack of knowledge about CO2-water-rock interaction within CO2 reservoirs and the potential risk of CO2 leakage. In this study, we construct a semi-open type experimental system that can reproduce the interactions under conditions close to those of actual CO2 reservoirs. Using the system, we conduct CO2-water-rock interaction experiments for 8 months to monitor the long-term reaction and the mobilization of harmful metal elements. Altered tuffaceous rock is used in the experiment because these tuffaceous rock formations (called 'Green Tuff') are a potential candidate for CO2 storage in Japan. The results show that the major-element water composition will converge to the point where host rock dissolution and secondary mineral precipitation are balanced; then, the interaction will proceed under a certain groundwater composition. In addition, we found that groundwater contamination by some metal elements (Ni, Ba, and Mn) may reach unsafe levels for drinking water as a result of CO2-water-rock interaction. [ABSTRACT FROM AUTHOR]

Lime is used for a wide range of processes and in a variety of products that are essential to our quality of life and to a sustainable European economy. This roadmap presents a reference pathway for the European lime sector to achieve negative CO2 emissions by 2050. It is estimated that by 2030, direct CO2 emissions will be achieved through fuel switch to decarbonized/low carbon energy vectors, as well as the first steps in the deployment of carbon capture utilization and storage (CCUS). By 2050, it is estimated that the European lime sector will deliver negative emissions. This will be achieved through full deployment of decarbonization technologies and techniques (crucially CCUS, fuel switch to decarbonized/low carbon energy vectors, and energy‐efficient/electrified kiln technologies) as well as by carbon removal from the atmosphere through lime carbonation during its use phase. The roadmap further explores the key prerequisites that will allow the industry to deliver a reduction in emissions. Altogether, this research demonstrates and quantifies the potential of the European lime sector to deliver net negative emissions by 2050, thus contributing to the overall carbon neutrality of European society. [ABSTRACT FROM AUTHOR]

To estimate the carbon dioxide (CO2) injection and storage capacity of saline formations, we used Tough2-ECO2N simulation software to develop a pressure-limited (dynamic) simulation approach based on applying three-dimensional (3D) numerical simulation only on the effective injection area (Aeff) surrounding each injection well. A statistical analysis was performed to account for existing reservoir heterogeneity and property variations. The accuracy of the model simulation results (such as CO2 plume extension and induced injection well bottomhole pressure values) were tested and verified against the data obtained from the Decatur CO2 injection study of the Mount Simon Formation. Next, we designed a full-field CO2 injection pattern by populating the core sections of this formation with a series of the simulated effective injection areas such that each simulated Aeff acts as a closed domain. The results of this analysis were used to estimate the optimum number and location of the required CO2 injection wells, along with the dynamic annual CO2 injection rate and overall pressure-limited storage capacity of this formation. This approach enabled us to model separate CO2 injection activities independently at different sections of the same saline formation and to model and simulate faults and natural barriers by considering them as boundary conditions for each simulated Aeff without constructing full-field models. Using this approach, a series of modeled Aeff with relevant properties may be redesigned to model any other saline formation with a similar structure. © 2017 The Authors. Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

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Carbon dioxide (CO2) emissions from power stations and industrial plants are seen as major contributors to what is known as the greenhouse gas (GHG) effect. Carbon dioxide capture and storage (CCS) is one technology which may reduce the quantity of CO2 released into the atmosphere but development of CCS has slowed due to the absence of a viable financial model. Metering technology is a prerequisite in enabling realistic financial decisions to be taken; however, there is currently a paucity of research into the types of flowmeters which would be suitable for incorporating into CCS transportation chains. This paper reviews and summarizes existing metering technologies with a view to establishing their suitability for measuring high mass flowrate, supercritical CO2. Open channel, differential pressure, velocity measurement, direct mass measurement, and electrical, magnetic, thermal, sonic, and radiation technologies are all considered. The challenges associated with each generic group are described, and recommendations made regarding the practicalities of using particular types of meter for CO2 transport in CCS applications. © 2016 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

Online impulse frequency response analysis (IFRA) method is proposed and developed as a new technique to detect the winding mechanical deformation of a running transformer. The preliminary application of IFRA has been realised by using the bushing capacitive coupling sensor (CCS). However, whether the installation of the sensor affects the normal operation of the transformer is still unknown. To study above problem, this study first establishes a simulation model for transformer bushing based on the finite‐element method and discusses the influence of sensor installation on the electric field distribution of capacitive bushing. The simulation proves that the installation of the CCS has minimal effect on the safe operation of the bushing. Second, the bushing withstand voltage tests are conducted in a lab, which proves that the installation of CCS meet the requirement for safe operation of capacitive bushing. Finally, the CCSs are installed on running power facilities, and the long and safe running experience indicates that the bushing and related facilities are unaffected by CCSs. The simulation analysis, withstand voltage test, and field application verify that the installation of CCS would not threaten the safe operation of high‐voltage bushing, laying the foundation for engineering application of IFRA. [ABSTRACT FROM AUTHOR]