“…These include rated and maximum powers, number of phases (three‐phase or a single‐phase DER), rated currents and voltages, internal impedance values, contractual obligations, points of common couplings (PCCs), network and circuit topologies, and the method used for connection to the grid, but also in the case of inverter based DERs (IBDERs), functionalities that inverters may provide (e.g., grid‐forming vs. grid‐following, frequency response, voltage support, ride‐through, etc.) (ABB, 2020; General Electric, 2021; Schneider Electric, 2019; Siemens, 2021; Strezoski et al, 2022; Strezoski & Stefani, 2021). Further, and on top of the accurate network model, to provide awareness of the precise grid conditions in real time, these software solutions must deploy state of the art power flow and state estimation algorithms that are constantly supplied by real‐time SCADA and Advanced Metering Infrastructure (AMI) measurements, load and generation forecasts, real‐time topology, and as‐operated switching state from the field, as well as planned schedules from DERs based on their market participation.…”