Decarbonization Of Energy System Research Articles

Identification of waste lithium-ion battery cell chemistry for recycling.

Battery technology has attained a key position as an energy storage technology in decarbonization of energy systems. Lithium-ion batteries have become the dominant technology currently used in consumer appliances, electric vehicles (EVs), and industrial applications. However, lithium-ion batteries are not alike and can have different cathode chemistries which makes their recycling more complex. In addition, as larger quantities of batteries are starting to enter their end-of-life (EOL) stage, efficient handling and management of batteries with different cathode chemistry types are required. By identifying the cathode chemistry type prior to mechanical treatment, mixing of different cathode chemistries could be decreased, resulting in an increase in overall recycling efficiency. This study investigated the applicability of a non-destructive battery diagnostic methods, namely incremental capacity analysis (ICA), for identifying EOL lithium-ion battery chemistry. The study conducted ICA both on known reference batteries and EOL batteries from the recycling industry. Next, EOL batteries were crushed and the resulting fine active material was analysed to validate the ICA result. In addition, released gaseous and airborne particles were measured during crushing. The ICA results showed reliable identification of lithium iron phosphate (LFP) from other chemistries. In addition, lithium cobalt oxide (LCO), lithium nickel cobalt aluminum oxide (NCA) and lithium nickel manganese cobalt oxide (NMC) could be identified with various degrees. The identification may suffer if the battery is heavily used, and its state of health is low.

Novel approach to achieving net-zero carbon emissions for development and utilization of coal: Principle, methods, and cost estimation.

China's energy mix is coal-dominated; therefore, it is unrealistic for the country to achieve carbon neutrality through complete decarbonization. As the world's largest carbon emitter, achieving global carbon reduction targets necessitates that China develops low-carbon, clean, safe, and efficient coal development and utilization technologies. This study proposes a new low-carbon coal development and utilization method that integrates in-situ conversion mining and mineral carbonation (ICMMC) to realize coal mining and separation, in-situ backfilling, in-situ conversion, energy storage, and carbon sequestration. This method addresses the technical bottleneck of slow mineral carbonation (MC) reaction rates that hinder the application of low-cost carbon sequestration engineering by utilizing in-situ backfilling strips to construct an in-situ carbonation repository, alongside a complementary in-situ layered carbonation process to enhance carbon sequestration efficiency. Life cycle assessment and levelized cost of electricity (LCOE) are employed to analyze the competitiveness and necessity of this new method compared to coal-fired power with carbon capture and sequestration (CPCCS) and onshore wind power with energy storage (OWPES) technologies. The results indicate that the carbon emissions of the ICMMC (0.091kg/kWh) are much lower than those of traditional coal-fired power, and its LCOE of 0.463 CNY/kWh has a cost advantage compared to both CPCCS and OWPES over the next seven years. The findings suggest that the ICMMC system can partially replace CPCCS and OWPES, helping to reduce global carbon reduction pressure; it can serve as a transition technology that supports the decarbonization of energy systems in countries where coal is the primary energy source.

A twenty-year dataset of hourly energy generation and consumption from district campus building energy systems

Distributed energy resources (DERs) would play a crucial role in the transition towards decentralized and decarbonized energy systems. However, due to the limited availability of long-term, high-resolution datasets, there has been little research on the descriptive analysis of distributed energy systems throughout the lifespan of distributed power generators and beyond. To address this challenge, this study has collected and described a twenty-year dataset (from 2002 to 2021) consisting of hourly energy generation and consumption profiles from a campus distributed energy system, covering the entire lifespan of on-site generators. The dataset includes supply-side data such as gas consumption from combined heating and power (CHP) units (fuel cell, gas engine), absorption chiller, gas boiler, solar photovoltaic generation, CHPs output, and grid electricity import. Additionally, real-life electricity, hot water, space heating, and cooling energy load profiles from individual buildings within the campus were also collected. This long-term dataset can be utilized in various scenarios, providing researchers and policymakers with comprehensive insights into the energy efficiency of distributed energy systems.

The Evolution of China's Domestic Climate Policy Frames (2009–2024): Problems, Solutions, and Motivations

ABSTRACTOver the past decade, The People's Republic of China has increased its influence in global climate governance. Despite the strong interest in policy frames related to climate change at the global level, few studies have explored policy frames within China. This paper therefore adopts a frame analysis to study the evolution in framing of domestic climate policies in China over the period 2009–24. Our research finds that diagnostic frames (the “problem”) identify development pressure, energy sector, and the impacts of natural disasters, pollution and ecosystem damage/change as key issues to be addressed. Prognostic frames (the “solutions”) encompass energy system decarbonization, industry reform, nature‐based solutions, market‐oriented solutions, and international cooperation. The motivational framings (the “ideational motivations”), include green development, ecological civilization, the principle of Common But Differentiated Responsibilities (CBDR), and multilateralism. The study reveals shifts in diagnostic, prognostic, and motivational frames of the national government across three periods.

Blockchain-based peer-to-peer renewable energy trading and traceability of transmission and distribution losses

In attempts to progress the transition towards decarbonizing energy systems and achieving sustainable development goals linked to energy, renewable energy sources (RES), which are decentrally deployed, are being widely promoted. However, RES are constrained by many barriers, some of which are technical in nature, such as energy losses. For instance, traditional peer-to-peer (P2P) trading systems have been used as a mechanism to advance RES because they offer a promising solution for decentralized energy trading without third-party intermediaries. However, it faces significant challenges, notably in accounting for energy losses during transmission and distribution, thus reducing overall system efficiency. We propose an end-to-end blockchain-based solution to provide traceability of energy loss in a distributed network and enhance transaction security, trust, and operational efficiency by linking prosumers and consumers. Our solution uses smart contracts to automate business transactions among the stakeholders. We develop six algorithms and deploy the smart contracts to demonstrate the successful deployment of the P2P energy trading process. Our solution effectively provides traceability of energy loss and reliably secured P2P energy transaction verification. We also present the cost and security analysis to demonstrate the affordability and reliability of our solution. We make our smart contract codes publicly available on GitHub.

Towards a Sustainable, Integrated, and Decarbonized Energy System in the EU: Addressing Structural Challenges Through Hydrogen System Planning

Towards a Sustainable, Integrated, and Decarbonized Energy System in the EU: Addressing Structural Challenges Through Hydrogen System Planning

A digital twin of multiple energy hub systems with peer-to-peer energy sharing

As climate change has become a global concern, the decarbonization of energy systems has become a prominent solution for CO2 emission reduction. The recent emergence of multi-energy hub systems (MEHs), characterized by interconnected energy hubs (EHs) and facilitated by energy sharing, presents a promising solution for seamlessly integrating a significant share of renewable energy sources (RESs) and flexibility among EHs. Faced with the intricate interplay and uncertainty of future energy markets, an extensive digital twin (EXDT) is proposed to perform predictive testing and evaluate the performance of MESs. This EXDT provides energy system operators with insights into the coordinated behavior of interconnected EHs under various future scenarios, thus contributing to smarter decision-making processes. Specifically, an array of scenarios including different decision-making strategies and P2P energy sharing strategies were considered. For each of these scenarios,"what-if" tests were conducted using a multi-agent reinforcement learning (MARL)-based method to model the stochastic decision-making process of EHs belonging to different stakeholders with access to local information. Uncertainties during operation can be mitigated using Markov Game (MG) by capturing knowledge from historical energy data. Subsequently, the economic and technical performance were evaluated using multidimensional evaluation indexes. The proposed MARL-based EXDT was applied to a representative 4-EH multi-energy system in China. Simulation results indicate that P2P energy sharing facilitates the local consumption of renewable energy, providing additional financial benefits and self-sufficiency to each EH and offering peak shaving to the upstream grid. Additionally, system performance under various decision-making and P2P sharing strategies was tested and evaluated to identify the impact of these strategies on system operation.

OM Forum—Asset-Level Perspectives on the Clean Energy Transition

Problem definition: The clean energy transition is an important component of the net zero transformation, which aims at averting potentially disastrous climate change related to excessive global warming by practically eliminating new global greenhouse gas emissions within 2050. The resulting move toward decarbonized energy systems is projected to encompass massive investments in assets that employ technologies with low environmental impact, some of which are innovative or yet unproven or even undeveloped, an area known as CleanTech. The typical analyses that are informing the dialogue on this process in practice provide insights into decarbonization paths at the technology level. In contrast, managers need to make decisions about assets. Methodology/results: Taking an asset-level view of the clean energy transition that complements its technology outlook, this essay provides a concise entry point into this topic based on both the practitioner literature and personal reflections, highlighting CleanTech innovations and related operational considerations in carbon capture, use, and storage; sustainable fuels; hydrogen; electricity; and concomitant government support activities. Managerial implications: Further, this work advocates for potential CleanTech research or teaching pursuits, especially ones aimed at directly supporting managerial decision making, for which it provides an example from the literature.

Establishing best practices for modeling multi-day energy storage in deeply decarbonized energy systems

Abstract Multi-day energy storage (MDS, a subset of long-duration energy storage or LDES) may become a critical technology for the decarbonization of the power sector, as current commercially available Li-ion battery storage technologies cannot cost-effectively shift energy to address multi-day or seasonal variability in demand and renewable energy availability. MDS is difficult to model in existing energy system planning models (such as electricity system capacity expansion models), as it is much more dependent on an accurate representation of chronology than other resources. Techniques exist for modeling MDS in these planning models; however, it is not known how spatial and temporal resolution affect the performance of these techniques, creating a research gap. In this study we examine what spatial and temporal resolution is necessary to accurately capture the full value of MDS, in the context of a continent-scale capacity expansion model. We use the results to draw conclusions and present best practices for modelers seeking to accurately model MDS in a macro-energy systems planning context. Our key findings are: 1) modeling MDS with linked representative periods is crucial to capturing its full value, 2) MDS value is highly sensitive to the cost and availability of other resources, and 3) temporal resolution is more important than spatial resolution for capturing the full value of MDS, although how much temporal resolution is needed will depend on the specific model context.

Decarbonized energy system planning with high-resolution spatial representation of renewables lowers cost

Decarbonized energy system planning with high-resolution spatial representation of renewables lowers cost

The impact of hydrogen on decarbonisation and resilience in integrated energy systems

The lack of clarity and uncertainty about hydrogen's role, demand, applications, and economics has been a barrier to the development of the hydrogen economy. In this paper, an optimisation model for the integrated planning and operation of hydrogen and electricity systems is presented to identify the role of hydrogen technologies and linepack in decarbonising energy systems, improving system flexibility, and enhancing energy system security and resilience against extreme weather events. The studies are conducted on Great Britain's (GB) 2050 net-zero electricity and gas transmission systems to analyse the hydrogen transport and capacity requirements within the existing infrastructure under different scenarios. This includes sensitivities on the level of flexibility, high gas prices, hydrogen production mixes, enabled reversibility of electrolysers, electricity generation cost, and hydrogen storage facilities. In all sensitivity scenarios, efficient hydrogen transport within the existing infrastructure is enabled by the optimal allocation of green and blue hydrogen sources, distributed storage facilities, and the intra-day flexibility provided by linepack. The findings highlight that increased renewable deployment transfers intermittency to the hydrogen network, requiring greater linepack flexibility compared to the current paradigm (up to 83%). Furthermore, the necessity of synergy between different gas and electricity systems components in providing flexibility, security, and resilience is quantified.

Fairness considered aggregation mechanism for consumers and prosumers in electricity distribution networks

Efficiently realizing a decarbonized energy system relies on effectively aggregating and equitably allocating cost to consumers and prosumers in distribution networks. This is crucial for fostering flexibility in transitioning to a sustainable, low-carbon energy system with increased renewable integration. This paper proposed an innovative aggregation mechanism for prosumers and consumers, emphasizing fairness and equality in their aggregation via proper pricing and efficient dispatching. The approach aims to enhance participant retention and attract investments by analysing characteristics, operation models, and operational impact on end users. The proposed two-level model underscores fairness and equity on different scopes. The upper-level model incorporates distributed nodal pricing (DNP) to facilitate fair dispatch among nodes, accounting for transmission congestion impacts. Simultaneously, the lower-level model addresses the efficiency-fairness trade-off, emphasizing equity in the energy sector and utilizing user satisfaction levels as the reference index. To validate the proposed aggregation mechanism, an example system is employed, with numerical studies illustrating its potential to enhance efficiency and fairness in the aggregation. A substantial improvement in the fairness index is observed when the efficiency-vs-fairness ratio changes from 1 to 0.9, indicating that even a modest emphasis on equity indicators can significantly enhance energy fairness.

Sodium Carbonate-Modified activated carbon catalysts for enhanced hydrogen production via methane decomposition

Hydrogen is a clean and renewable energy source with significant potential for decarbonizing energy systems. Methane decomposition offers a sustainable method for hydrogen production without the emission of COx gases, making it as an attractive alternative to conventional methods like steam reforming. However, the high energy consumption associated with methane decomposition presents a challenge. To address this challenge, this study explores the modification of activated carbon (AC) with sodium carbonate (Na2CO3) to enhance its catalytic efficiency in methane decomposition. Various concentrations of Na2CO3 were used, and the catalysts were thoroughly characterized using XRD, SEM, and N2 adsorption–desorption techniques to evaluate their porosity, surface area, and crystallinity. The results indicate that Na2CO3-modified AC significantly reduced the degree of graphitization, resulting in a disordered carbon structure with enhanced porosity. This structure effectively enhances the catalytic activity of AC, with the optimal catalyst being AC-2Na2CO3. After 150 min of reaction, the methane conversion rates at 850 °C, 900 °C, and 950 °C are 17.18 %, 20.19 %, and 31.33 %, respectively, representing increases of 5.19 %, 5.69 %, and 5.32 % compared to the unmodified catalyst. These improvements are attributed to the creation of more active sites for methane adsorption and dissociation. Overall, the study demonstrates the potential of Na2CO3-modified AC as an efficient catalyst for methane decomposition, offering a viable pathway for sustainable hydrogen production with reduced energy consumption.

Integrated assessment of levelized costs of hydrogen production: Evaluating renewable and fossil pathways with emission costs and tax incentives

The transition towards a sustainable hydrogen economy is driven by the need to decarbonize energy systems. This study presents a comprehensive analysis of the levelized cost of hydrogen (LCOH) from renewable sources and fossil-based production pathway with carbon capture and storage (CCS). The analysis integrates emissions assessments, tax credits under the Inflation Reduction Act (IRA), and employs sensitivity analyses to provide a holistic understanding of the economic viability and critical cost considerations. The results reveal that hydrogen production pathways that leverage Wyoming's nuclear and wind energy resources can be competitive with fossil-based production by utilizing existing IRA incentives. However, the capital costs of electricity production facilities and electrolyzers greatly influence the LCOH. For fossil-based hydrogen production, the cost of emissions, natural gas and electricity significantly impact the LCOH, underscoring the importance of optimizing energy consumption and securing affordable feedstock. This study identifies blue hydrogen as a balanced strategy for Wyoming to transition into a regional hydrogen hub, providing valuable insights into the economic and environmental considerations for fossil centric energy economies.

REVIEW OF GREEN HYDROGEN TRANSFORMATION TECHNOLOGIES FOR INCREASING BIOMETHANE PRODUCTION AT EXISTING PLANTS IN UKRAINE AND EUROPE

Objective: The objective of this review is to analyze the technologies for transforming green hydrogen to enhance biomethane production at existing plants in Ukraine and Europe, and to assess their potential in the context of achieving climate neutrality and energy independence. Tasks: Evaluate the European Union's strategies for achieving climate neutrality with an emphasis on the use of green hydrogen. Examine the technologies for integrating green hydrogen into biomethane production at operational biogas plants. Analyze the prospects and challenges of implementing such technologies in Ukraine and Europe. Research Methods: To achieve the objectives, methods of review analysis, comparison of existing technologies, and assessment of their economic and environmental effectiveness were used. Information was gathered from scientific publications, official reports of the European Union, as well as data on the current state and prospects of the biogas and biomethane market. Results: The article analyzes EU strategies aimed at achieving climate neutrality by 2050 through the active use of green hydrogen. Green hydrogen, produced from renewable energy sources, is a key component in the decarbonization of energy systems. Integrating green hydrogen into biomethane production allows for significant reductions in greenhouse gas emissions and enhances energy independence. European plants are already successfully employing water electrolysis and methane synthesis technologies to convert CO₂ into biomethane. These technologies provide additional opportunities for energy storage and reduction of CO₂ emissions. Technologies such as hydrogenotrophic CO₂ reduction have shown high potential in biomethane production using green hydrogen. In Ukraine, the development of biomethane and hydrogen infrastructure is also outlined in the "Memorandum of Understanding" with the EU. These investments are expected to contribute to the country's energy independence and reduction of greenhouse gas emissions. However, achieving this potential requires overcoming regulatory barriers and securing appropriate investments. Thus, integrating green hydrogen into biomethane production is an important step towards clean energy and sustainable development both in Ukraine and in Europe. Further research and investment in this field will contribute to achieving climate goals and enhancing energy security.

Optimum carbon tax rate for emission targets of electricity generation system by life cycle techno-economic-environmental optimization model

Reduction of greenhouse gas emissions from the electricity sector is of special interest for decarbonization of energy systems. Optimum carbon tax as a powerful policy tool is here studied by integrated techno-economic-environmental life cycle analysis in a unit commitment problem. The present model is formulated as a bi-level optimization problem to reach the optimum carbon tax rates for different emission targets. The total life cycle CO2 emissions are estimated to be 20333.90 tons/hr in a real case study of Iran's electricity sector for the peak demand hour. The carbon tax rate for a 2 % and a 3 % emissions reduction is equal to 15.87 and 24.65 $/ton, respectively. In the business-as-usual scenario, higher carbon taxes will be required each year to meet the same emission target. However, developing the electricity sector with cleaner technologies and strategic plans may decrease the carbon tax rate. The extent of this reduction depends on the type of development program implemented in the green revolution scenario. Therefore, policy makers play a direct role in ensuring the sustainable development of the electricity sector. The present model provides a robust framework to analyze the real carbon tax rates for the whole life cycle of electricity generation dispatch.

Dual-objective optimization of solar driven alkaline electrolyzer system for on-site hydrogen production and storage: Current and future scenarios

Achieving cost competitiveness of renewable hydrogen could accelerate the transition to the deeply decarbonized energy system. In this article, we develop and apply a dual-objective optimization model to explore the photovoltaic (PV) hydrogen production pathway and costs development from the present through 2050. The model is applied for optimal capacity allocation of the megawatt-scale off-grid PV-Hydrogen system to achieve maximum production at the minimal levelized cost of hydrogen (LCOH). Methodology includes a smoothing control strategy. Simulation is performed utilizing measured meteorological data for one year with hourly resolution and considering electrolyzer's load flexibility constraint. It has been found that the smoothing control strategy is indispensable for maximizing PV energy utilization, enhancing the electrolyzer's capacity factor and reducing the power curtailments. The analysis shows that the off-grid solar hydrogen in Algeria lacks economic competitiveness currently. Components CAPEX reduction turns out to be the fundamental condition towards the future LCOH decrease. LCOH could decline from 4.2 $/kg in 2025 to 2.24 $/kg in 2050 under central assumptions and to roughly 1.4 $/kg under optimistic assumptions. Alkaline electrolysis step cost could reduce by 0.28 $/kg every decade. Hydrogen storage autonomy could rise the LCOH by 7.1 c$ per day of autonomy in 2050.

Hydrogen Valleys for Local Energy System Decarbonization: An Assessment of the Environmental and Economic Aspects

Abstract The necessity to address the adverse impact of global climate change has led to the widespread adoption of clean energy and the prioritization of decarbonising “hard-to-abate” sectors. This work aims to investigate the environmental and economic aspects of a Hydrogen Valley to facilitate the decarbonization of local energy systems and to integrate the hydrogen value chain across various stages from production to utilization. The southern Italian province of Taranto was selected for the case study, and the energy system is modelled in EnergyPLAN software considering the ‘business as usual’ scenario. The levelized cost of hydrogen (LCOH) is calculated, and its variation with the installation cost of the electrolyser is analysed. The result shows that the carbon emissions and total annual costs of the business-as-usual scenario are 4.098 Mt of CO2 emissions and 0.98 billion euros, respectively. The levelized cost of hydrogen is found to be 4.09 €/kg. A 71.4% reduction in capital expenditure (CAPEX) will decrease the levelized cost of hydrogen (LCOH) to 2.78 €/kg, highlighting the crucial role of cost reductions in electrolyser technologies for achieving a lower levelized cost of hydrogen.

An exploration of the wake of an in-stream water wheel

Research on low-impact, low capital-cost hydropower is increasing as efforts to decarbonise energy systems accelerate. The in-stream water wheel can potentially aid in this decarbonisation effort, but there is little research into the fluid environment around these turbines. This is despite the potential impact that the fluid environment can have on turbine power characteristics and hydrography of the local stream. This paper provides a qualitative analysis of the wake of an in-stream water wheel using dye injection and analysis, supported by quantitative analysis of the near-wake using particle image velocimetry. The results demonstrate that the wake of an in-stream water wheel is primarily characterised by large periodic vortices generated by the shedding of the leading edge vortex as the blade rotates through the fluid, with smaller counter-rotating vortices shed as the local flow angle reverses near the blade entry and exit. The wake maintains a coherent structure three diameters downstream of the turbine, which could potentially impact the power generation of downstream turbines. This wake coherence is largely consistent across different numbers of turbine blades and blade depth ratios.

Hourly electricity CO[formula omitted] intensity profiles based on the real operation of large-scale natural gas combined cycle cogeneration plants

The decarbonization of energy systems is a major challenge that requires complex cross-sectoral strategies that need to be supported by energy modeling. As many technologies rely on electricity, an accurate estimation of its CO2 intensity is of utmost importance for the reliability of modeling results. When electricity is generated from fossil sources, its CO2 intensity depends on several parameters. This research paper presents an hourly calculation of the CO2 intensity of power generation from natural gas combined cycles, based on real data from several years of operation of three plants. As these plants are also operated in combined heat and power mode, two alternative allocation methods are compared. The results confirm the variability of CO2 intensity based on the different operation strategies of the plants and the share of heat and electricity generated. The hourly analysis shows average values in the range of 230–250 gCO2/kWh in winter, rising to around 330–370 gCO2/kWh in summer. The real CO2 intensity profiles presented in this paper can be integrated into energy planning models to improve their ability to estimate the potential benefits of different decarbonization solutions by including the effect of the operational profiles over the day and the year.