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This paper presents an approach to deploy virtually settled peer-to-peer (P2P) energy trading in existing grid-connected networks without considering post-trading protection schemes that may be required for bus voltage regulation. To achieve this goal, this paper demonstrates to consider the maximum power export limit fixed by the network operators while modelling the P2P trading framework in the virtual layer and then to determine the traded quantity of each prosumer in the P2P market along with the associated price per unit of energy traded. The developed P2P mechanism in this paper is tested on a real low-voltage (LV) distribution network in Australia, where the maximum local power injection limit has already been defined for the prosumers. The simulation results show that both prosumers and other customers of the network can still be benefited significantly, compared to the current feed-in-tariff (FiT) and electricity retail prices respectively, even though P2P traded quantities are regulated by the network operator. It is also observed that the prosumers’ engagement in P2P trading at various time slots do not rise bus voltages beyond the prescribed limit. Thus, virtually settled P2P transactions considering the power export constraint are suitable for practical deployment.

This paper presents an approach to deploy virtually settled peer-to-peer (P2P) energy trading in existing grid-connected networks without considering post-trading protection schemes that may be required for bus voltage regulation. To achieve this goal, this paper demonstrates to consider the maximum power export limit fixed by the network operators while modelling the P2P trading framework in the virtual layer and then to determine the traded quantity of each prosumer in the P2P market along with the associated price per unit of energy traded. The developed P2P mechanism in this paper is tested on a real low-voltage (LV) distribution network in Australia, where the maximum local power injection limit has already been defined for the prosumers. The simulation results show that both prosumers and other customers of the network can still be benefited significantly, compared to the current feed-in-tariff (FiT) and electricity retail prices respectively, even though P2P traded quantities are regulated by the network operator. It is also observed that the prosumers’ engagement in P2P trading at various time slots do not rise bus voltages beyond the prescribed limit. Thus, virtually settled P2P transactions considering the power export constraint are suitable for practical deployment.

Abstract Uncertainties at end-user and aggregator levels can be highly detrimental to the practical implementation of residential load control schemes for electricity market applications. Uncertainty factors such as end-user non-compliance, comfort violations and load set-point changes associated with the demand response aggregator are unavoidable in practice. This paper proposes a novel two-stage control algorithm for robust centralised management of aggregate residential loads which guarantee precise load set-point tracking in the presence of uncertainties occurring in real-time while ensuring that end-user thermal comfort is not compromised. The approach is underpinned by optimal selection of appliances based on an emulated supply curve followed by solving a one-step-ahead optimisation problem. Using air conditioners and water heaters as the controllable loads, the paper illustrates the effectiveness of the proposed approach in load management whilst mitigating the effects of unknown uncertainties. Further, the developed control scheme is compared with an existing industry approach. The results yield that the proposed control scheme is robust to uncertainties, preserves thermal comfort and is applicable for practical implementation under existing demand response standards.

Abstract Uncertainties at end-user and aggregator levels can be highly detrimental to the practical implementation of residential load control schemes for electricity market applications. Uncertainty factors such as end-user non-compliance, comfort violations and load set-point changes associated with the demand response aggregator are unavoidable in practice. This paper proposes a novel two-stage control algorithm for robust centralised management of aggregate residential loads which guarantee precise load set-point tracking in the presence of uncertainties occurring in real-time while ensuring that end-user thermal comfort is not compromised. The approach is underpinned by optimal selection of appliances based on an emulated supply curve followed by solving a one-step-ahead optimisation problem. Using air conditioners and water heaters as the controllable loads, the paper illustrates the effectiveness of the proposed approach in load management whilst mitigating the effects of unknown uncertainties. Further, the developed control scheme is compared with an existing industry approach. The results yield that the proposed control scheme is robust to uncertainties, preserves thermal comfort and is applicable for practical implementation under existing demand response standards.

Dynamic operating envelopes (DOEs) are promising to cater for the strong uptake of distributed energy resources (DERs) in low-voltage (LV) distribution networks while ensuring secure network operation. Under the current framework, DOEs only specify active-reactive power set-points at households' point of connection (POC). In this regard, DOEs do not provide information on the feasible operating region (FOR) of end-users, which is helpful for an aggregator's market decisions. This article proposes a near real-time approach to determine DOEs that specify the FOR at end-users' POC in an LV distribution network. First, Latin hypercube sampling (LHS)-based load flow studies are performed to identify feasible pairs of P-Q injections at the POC that would not breach voltage limits. Secondly, the convex hull of feasible pairs is constructed to obtain household DOEs. Finally, a feeder-level time-varying envelope that represents the aggregate flexibility of downstream nodes of the network is calculated. A comprehensive analysis on a real Australian LV distribution network using realistic data suggests that the proposed approach is scalable and encourages active power exports beyond current industry practice. Moreover, the framework ensures privacy and separation between the distribution network service provider (DNSP) and the aggregator aligned with the existing policy and regulatory frameworks.

Dynamic operating envelopes (DOEs) are promising to cater for the strong uptake of distributed energy resources (DERs) in low-voltage (LV) distribution networks while ensuring secure network operation. Under the current framework, DOEs only specify active-reactive power set-points at households' point of connection (POC). In this regard, DOEs do not provide information on the feasible operating region (FOR) of end-users, which is helpful for an aggregator's market decisions. This article proposes a near real-time approach to determine DOEs that specify the FOR at end-users' POC in an LV distribution network. First, Latin hypercube sampling (LHS)-based load flow studies are performed to identify feasible pairs of P-Q injections at the POC that would not breach voltage limits. Secondly, the convex hull of feasible pairs is constructed to obtain household DOEs. Finally, a feeder-level time-varying envelope that represents the aggregate flexibility of downstream nodes of the network is calculated. A comprehensive analysis on a real Australian LV distribution network using realistic data suggests that the proposed approach is scalable and encourages active power exports beyond current industry practice. Moreover, the framework ensures privacy and separation between the distribution network service provider (DNSP) and the aggregator aligned with the existing policy and regulatory frameworks.

This paper introduces a new method for allocating losses in a power system using a loop-based representation of system behaviour. Using the new method, network behaviour is formulated as a series of presumed power transfers directly between market participants. In contrast to many existing loss allocation methods, this makes it easier to justify the resulting loss distribution. In addition to circumventing the problems of non-unique loss allocations, a formalised process of loop identification, using graph theory concepts, is introduced. The proposed method is applied to both the IEEE 14-bus system and a modified CIGRE Nordic 32-bus system. The results provide a demonstration of the capability of the proposed method to allocate losses in the hybrid market, and demonstrate the approach's capacity to link the technical performance of the network to market instruments.