Distributed energy resources, together with information and communication technologies, have transformed the traditional electricity consumers into proactive consumers, namely prosumers. Prosumers can exchange their surplus energy with consumers through peer-to-peer (P2P) energy sharing. In this paper, the framework of P2P energy exchange in active distribution networks is developed using a multi-round double auction (MRDA) with average pricing mechanism (APM) integrated with distributional locational marginal price. The advantages of the proposed P2P framework include, 1) modeling and integration of the costs of voltage regulation, congestion, and power loss into the payments of agents for each transaction; 2) the entire distribution network clustered into multiple zones with transactions cleared at different levels, which decreases the additional costs for successful transactions, reduces the computational time, and increases the number of successful transactions; and 3) the matching algorithm encourages more prosumers and consumers to participate in P2P energy sharing and increases the efficiency and benefit from P2P market. The proposed MRDA-APM framework is validated by testing on the 33-node and 141-node distribution test systems. Simulation results demonstrate the effectiveness of the proposed mechanism for P2P energy exchange from both technical and computational viewpoints.

Deploying distributed energy resources and other smart grid technologies have increased the complexity of power grids and made them more vulnerable to natural disasters and cyber-physical-human (CPH) threats. To deal with these extreme events, proactive plans are required by utilities to minimize the damages caused by CPH threats. This article proposes a proactive rolling-horizon-based scheme for resilience-oriented operation of hydrogen (H2) systems in integrated distribution and transmission networks. The proposed framework is a bilevel model in which the upper level is focused on distribution system operation in both normal and emergency operation modes, and the lower level problem accounts for the transmission network operation. Two preeminent aspects of H2 systems are considered in this article. First, to show the flexibility of H2 systems, capacity-based demand response signals are considered for electrolyzers, stationary fuel cell (FC) units, and H2 storage tanks are considered in both normal and emergency operation modes. Second, unlike the batteries that can only charge and discharge energy based on maximum duration times and power ratings, H2 systems can be considered as the flexible long-term energy storage by storing H2 for days and supplying power to FC in the case of N-m outages lasting for more than 10 h. Moreover, the H2 production cost based on water electrolysis and storage costs is calculated. Simulation results demonstrate that utilities can improve the system-level resilience using H2 systems as long-term backup power resources.

Environmental emissions and decreasing costs of renewable energy sources (i.e., photovoltaic (PV), wind, hydrogen (H2), etc.) are prompting a sharp increase in renewable energy penetration into the grid. Among various energy sources, H2 energy with its promising technical, economic, and environmental merits has demonstrated great potential for large deployment in distribution systems. This article proposes a multiobjective network-constrained framework for the day-ahead scheduling of hydrogen systems (HS), including hydrogen production from water electrolysis by electrolyzers, hydrogen storage, stationary fuel cells, and fueling of fuel cell electric vehicles (FCEVs). This framework includes various physical constraints to ensure reliable operation and considers integrated demand response and conservation voltage reduction, and reactive power support from HSs for realistic day-ahead scheduling. It also incorporates the cooperative operation of PV units and HSs to supply power for water electrolysis from stationary HSs equipped with onsite PVs. Moreover, conditional value-at-risk is applied to address the risk of PV output, FCEVs’ H2 demand, loads, and market price. The proposed model is formulated as a mixed-integer linear programming problem and validated by testing on a 33-node distribution test feeder.

Deep energy decarbonization cannot be achieved without high penetration of renewables. At higher renewable energy penetrations, the variability and intermittent nature of solar photovoltaic (PV) electricity can cause ramping issues with existing fossil fuel generation, requiring longer term energy storage to increase the reliability of grid operation. A proton exchange membrane electrolyzer can produce H ₂ and serves as a utility controllable load. The produced H ₂ can then be stored and converted back into electricity, or mixed with natural gas, or used as transportation fuel, or chemical feedstock. This paper considers the perspective of the distribution system operator that operates the distributed energy resources on a standard IEEE 33-node distribution network considering the technical and physical constraints with the goal of minimizing total investment and operation cost. Different case studies, at very high PV penetrations are considered to show the challenges and path to net-zero emission energy production using H ₂ energy. Sensitivity of utility PV costs and electrolyzer capital costs on producing H ₂ at $1/kg are presented showing that the distribution network could produce 100% renewable electricity and H ₂ could be produced at a cost of $1/kg by 2050 with conservative cost estimates and by 2030 with accelerated cost declines.

The interdependence of cyber and physical infrastructures in hydrogen-integrated power systems introduces significant cybersecurity challenges for the reliable and secure delivery of sustainable energy. Addressing these challenges requires a thorough understanding of potential attack surfaces and their impacts, alongside the development of effective defense and mitigation strategies. This paper provides a comprehensive analysis of the inherent cyber-physical vulnerabilities within these systems, followed by an evaluation of the potential effects of cyberattacks on system performance. A tri-level attack-defense model is proposed, where the upper level examines attacker strategies and the two lower levels focus on defense mechanisms. The middle level addresses operational strategies for the hydrogen system, while the lower level is dedicated to distribution system operations, facilitating effective management of third-party hydrogen integration. Additionally, a stealthy attack model is introduced to simulate the sophisticated capabilities of modern attackers, designed to bypass traditional detection methods. A multiwave attack is analyzed to assess the model's resilience, and sensitivity studies are conducted to evaluate robustness. The effectiveness of the proposed model is validated through various attack scenarios on modified 15-node, 33-node, and 69-node test systems. Simulation results highlight the impacts of cyberattacks and demonstrate the efficacy of the developed attack-defense model.

Climate change is one of the most preeminent challenges facing the world. Continued fossil fuel energy consumption at the current trajectory will result in a temperature rise of more than 3.5°C by the year 2050. Melting glaciers, rising sea levels, wildfires, floods, and extreme weather events such as heat waves and large storms, are likely to become more frequent or more intense. The Paris Agreement is a legally binding international treaty to reduce carbon emissions which led to keep the global temperature rise well below 2°C [1]. This target cannot be achieved without deeply decarbonized energy production which focuses on three main factors: 1) Reducing energy consumption through improved efficiency (optimize), 2) Shifting energy demand to electricity and away from combustion of fossil fuels (electrify everything), 3) Shifting entirely to zero-carbon technologies such as solar photovoltaic (PV), wind, hydrogen, etc. to generate electricity (decarbonize). According to the United States (U.S.) Environmental Protection Agency (EPA), the largest contributors to anthropogenic U.S. greenhouse gas emissions in the descending order are transportation (29%), electricity (25%), industry (23%), agriculture (10%), commercial (7%), and residential (6%) [2]. In our previous research, we focused on decarbonization pathways using utility solar, hydrogen consumption and production (electrolyzer, compressor, storage tank, and stationary fuel cells) for improved utilities operation without considering transportation sector demand [3]. Here the focus is on energy decarbonization for both power and hydrogen fueled transportation sector using hydrogen systems. To this end, a vertically integrated 33-node distribution network which is managed by distribution system operator (DSO) is optimized. The DSO manages all the assets in the network including natural gas power plants (combined cycle units and combustion turbine units), solar PV, distributed energy storage systems, hydrogen systems (including storage and refueling station) with the objective of cost minimization. Besides managing the aforementioned technologies, the DSO ensures safe and reliable operation of these assets by considering the technical and physical constraints of the network including voltage regulation, power flow and line congestion management, etc. The DSO in this study also manages the transportation sector hydrogen demand of fuel cell electric vehicles, medium- and heavy-duty vehicles. Simulation results show that hydrogen demand from the transportation sector is the main driver in sizing of hydrogen system components. Additionally, for the 33-node distribution network to fully supply heavy-duty vehicles demand, natural gas power plants must be operated to supply the required electricity for the electrolyzers to supply hydrogen for these vehicles. Furthermore, different sensitivity analysis for various PV and hydrogen demand penetrations will be presented.