Abstract
In a transactive energy market, distributed energy resources (DERs) such as dispatchable distributed generators (DGs), electrical energy storages (EESs), distribution-scale load aggregators (LAs), and renewable energy sources (RESs) have to earn their share of supply or demand through a bidding process. In such a market, the distribution system operator (DSO) may optimally schedule these resources, first in a forward market, i.e., day-ahead, and in a real-time market later on, while maintaining a reliable and economic distribution grid. In this paper, an efficient day-ahead scheduling of these resources, in the presence of interaction with wholesale market at the locational marginal price (LMP), is studied. Due to inclusion of EES units with integer constraints, a detailed mixed integer linear programming (MILP) formulation that incorporates simplified DistFlow equations to account for grid constraints is proposed. Convex quadratic line and transformer apparent power flow constraints have been linearized using an outer approximation. The proposed model schedules DERs based on distribution locational marginal price (DLMP), which is obtained as the Lagrange multiplier of the real power balance constraint at each distribution bus while maintaining physical grid constraints such as line limits, transformer limits, and bus voltage magnitudes. Case studies are performed on a modified IEEE 13-bus system with high DER penetration. Simulation results show the validity and efficiency of the proposed model.
Highlights
Market-driven operation of the electric distribution system has recently gained considerable research momentum due to an increasing deployment of various distributed energy resources (DERs) such as renewable energy sources (RESs), electrical energy storages (EESs), dispatchable distributed generation (DG) units, and load aggregators (LAs) [1,2,3,4]
An outer approximation of the above ij,t convex quadratic constraint has been leveraged to linearize the line flow constraints in order to use in the proposed mixed integer linear programming (MILP) model
Two DGs were allocated in Buses 7 and 13
Summary
Market-driven operation of the electric distribution system has recently gained considerable research momentum due to an increasing deployment of various distributed energy resources (DERs) such as renewable energy sources (RESs), electrical energy storages (EESs), dispatchable distributed generation (DG) units, and load aggregators (LAs) [1,2,3,4]. In addition to the aforementioned DER types, distribution grid constraints such as line limits, transformer limits, and bus voltages are key considerations in the design of the DSO’s market. In [16], a distribution market operator has been introduced that administers optimal scheduling of DERs, which include DGs and loads, while interacting with the ISO This model does not include EES units and grid constraints such as bus voltages. We propose a day-ahead transactive energy auction for a DSO with high penetration of DERs, including DGs, EES units, LAs, and RESs, while considering distribution grid constraints. By allowing power injections at wholesale LMP, the DSO runs a double auction based on bids from different types of DERs to maximize social surplus while accounting for line limits, transformer limits, bus voltages, and the DER’s constraints.
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