To identify the trends in new flexibility markets, a set of market and aggregator platforms were selected and compared. The analyzed initiatives are relevant to consider alternative designs for European electricity markets. This review proposes a common methodology for analyzing these market models by comparing their description, market structure, market timing, and implementation. Furthermore, a range of policy implications and future research directions towards implementing these markets are presented. The results provide compelling evidence that the new market models represent a promising business with technical and economic justification, as they incentivize the uptake of flexibility from distributed resources by providing services to Distribution System Operators (DSOs) in coordination with Transmission System Operators (TSOs). Moreover, the interactions between these new market platforms and existing markets are of particular interest, and the contributions from aggregator platforms are also relevant to enhance the political vision of empowering the customers through their active participation in markets.

Purpose of Review: Non-firm (flexible) grid connection agreements are emerging as a fast, lower-cost alternative to traditional firm access for integrating renewable and distributed energy resources (DERs). This review examines: Which types of non-firm agreements exist, how are they implemented, and what lessons can be drawn from recent regulatory pilots? Recent Findings: Literature and pilot projects reveal four predominant models of non-firm grid connections: capacity-limited, time-limited, dynamic operating envelopes, and fully flexible based access. These models are being formalised through legislation or regulatory guidance in the United Kingdom, Australia, Spain, and in various countries of the European Union. Their implementation is increasingly supported by digital monitoring and growing links to local flexibility markets. Summary: Flexible connections can reduce connection costs by up to 80% and halve leadtimes, while safely expanding hosting capacity. Key challenges are curtailment predictability, compensation, and alignment with emerging market platforms. Clear, standardised regulatory frameworks and interoperable digital solutions are essential for scaling these agreements and accelerating DER integration.

The optimal transmission switching (OTS) looks to find the optimal network topology. This new control functionality enhances the power system flexibility to adapt to the future changing conditions. This paper incorporates the OTS in the unit commitment problem with a probabilistic reserve criterion, here the spinning reserve (SR) is determined by minimizing the total cost where the cost related to the expected load not served (ELNS) is penalized in the objective function. To reduce the computational complexity, a transmission line categorization scheme is introduced for screening a small set of switchable lines, and the maximum number of switchable lines is determined by a heuristic procedure. By doing so, the computation efficiency can be greatly improved. The case studies illustrate the validity and effectiveness of the proposed method.