Inverter-based resources (IBRs) are an intermittent source of energy, and their increased integration into power systems significantly reduces the physical inertia provided by synchronous generators, which account for about 20 % of gas emissions. This solution to global warming has created a problem of inertia response for the power system. The adequate control of these IBRs to provide virtual inertia should consider their percentage contribution capacity and existing grid energy storage, which are mostly battery energy storage systems (BESS). However, conventional control methods often fail to account for these critical features. This omission exacerbates the challenge of maintaining frequency stability in low-inertia grids, particularly in developing countries where centralized control architectures may be costly or impractical. This paper proposes a Hybrid Distributed Model Predictive Control (HD-MPC) strategy to coordinate 15 units of 100 kW flywheel energy storage systems (FESS) and 500 kW BESS, respectively, for virtual inertia support and fast frequency response in a two-area load frequency control (2A-LFC) system. The distributed framework enables each local area to operate semi-independently, thereby reducing communication burdens and enhancing resilience against delays or failures. Simulation results on MATLAB/SIMULINK of a 30 MW 2A-LFC model demonstrate that, in the event of 1 MW disturbances, the proposed HD-MPC approach outperforms conventional centralized MPC and uncontrolled cases by improving frequency nadir, reducing tie-line oscillations, and ensuring efficient BESS utilization. The results and validation of the mathematical model coding using Python highlight the viability of hybrid FESS–BESS coordination to improve frequency stability in inverter-dominated power systems, offering a scalable and practical solution for developing countries transitioning to IBR-dominated grids.