Distributed energy infrastructure has transformed how power is managed, generated, and delivered.
According to the U.S. Department of Energy (DOE), meeting rising clean energy and electrification goals requires a projected 60% increase in U.S. transmission capacity by 2030. DOE reports that “over 70% of transmission and power transformers in the U.S. energy infrastructure are 25+ years old.”Â
The core pressure point for managing two-way power flows is the global grid distribution networks. And they require roughly 50% more investment to enable local systems to adapt to “surging local demands.”
Grid Transmissions Then and NowÂ
Legacy centralized power plants and the grid were designed to move power in one direction: from large power plants, through transmission lines to residential and commercial customer sites.Â
Today, over 9,200 electric generating units stretch across the U.S., harnessing over 1 million megawatts of capacity. These sites operate different equipment from different vendors.Â
What’s alarming is that millions of data points are generated every hour across today’s distributed energy, alternative energy, and legacy generation assets, yet they remain siloed, untapped, or worse, totally ignored.Â
Digitization, integrated renewable energy sources, and electric vehicles (EVs) – among others – are overloading bidirectional networks. EVs alone will scale eightfold globally, from 30 million in 2022 to roughly 240 million by 2030, further taxing bidirectional charging and storage capabilities. But the American Society of Civil Engineers (ASCE) infrastructure report card rates the U.S. energy sector a D+, underscoring the urgent need for modernization to support dynamic bidirectional loads.
Empowering Data in Bidirectional Power Grid Network
Reliable electricity delivery is now at the core of our “electrified” daily life. Grid modernization’s “smart grid” has introduced upgraded technologies and an electrical network using digital technology, sensors, and two-way communication to manage the electricity flow in real time.Â
Residential and commercial energy consumers are no longer simply energy users. They are also energy suppliers. Â
A bidirectional grid also measures electricity flowing in both directions–energy delivered to consumers or commercial entities from the grid, and energy received from these sources.Â
Decentralized energy equipment allows reverse flow for both power and data -- easily supplying power to residential and commercial customers, as well as generators, storage systems, and other distributed energy resources.Â
As the “new world order,” the bidirectional power flow facilitates renewable energy sources (RES) integration into the grid. This allows electricity to flow not only from central plants to consumers but also from decentralized sources, like rooftop solar panels and wind turbines, back into the main utility grid. Managing renewable energy generation allows power loads to safely store excess energy during low-demand periods and reverse direction to send it back to the grid during high-demand periods.Â
Bidirectional grids also support decentralized power inputs and boost local municipal microgrids and other energy assets, while maintaining uninterrupted operations during power outages. The adoption and rapid integration of distributed energy resources (DERs) connected at the grid edge require decentralized utility operations to predict output and maintain reliability while optimizing grid operations.Â
Intelligent MonitoringÂ
Regardless of how many renewable sources consumers have installed, they still need to draw electricity from the grid during periods of low wind, cloudy weather, or nighttime when consumption exceeds generation. When consumers generate more electricity than they use, they can send excess energy back through the meter into their local distribution system. This system records and measures the energy produced by the consumer in kilowatt-hours (kWh). Local and municipal regulations, as well as utility tariffs and programs, determine whether the energy sourced by the consumer can be used to offset a bill, replace a payment, or provide credit to the consumer.
 Measured and conducted with Encoder Receiver Transmitter (ERT) channels, which track and transmit multi-directional energy metrics across a smart grid, these channels allow utility companies to measure and collect distinct metering values for billing and operations. For commercial clients, the third value can either be net energy (the difference between delivered and received energy -important for net metering) or peak demand measured in kilowatts, which affects billing based on their highest power draw. The third channel also represents reactive energy, time-of-use energy, or other specific metrics.
Utility operators are facing increasingly drastic weather conditions that put the energy grid at risk. Exacerbating this are critical data gaps that must be addressed. Such weather-dependent solar and wind sources will continue to fluctuate, leading to rapid shifts in voltage spikes and frequency, mostly at the grid edge.
With real-time data visibility into millions of decentralized entry points at the distribution edge, operators can closely monitor, manage, and triage problems before they lead to major power outages and costly operational disruptions. Not to mention damaging business profiles.
As the energy industry moves toward more intelligent monitoring of distributed generation, operators face the challenges of managing, operating, and monitoring a vast array of devices and equipment as they expand to new sites.Â
Managing distributed assets through a centralized, data-driven, real-time monitoring system allows on-site, remote, and field teams to easily monitor, control, and optimize their distributed energy portfolios in real time, regardless of their location. To help preempt operational risks, utility operators must get ahead of maintenance and equipment failure to avert power delivery disruptions and power outage risks.Â
One strategy is to close the IT and OT divide. This will allow operators to use a layered, unified, remote monitoring platform that connects every asset type across distributed sites into a single operational model. This will provide operators with real-time access to critical information and data, including storage, energy generation, grid infrastructure, and the overall health of their distributed sites.
Real-time monitoring decreases truck rolls, preempts required repairs to unmanned sites, and eliminates service delivery interruptions. When utility operators can control predictive and smart alerting systems, they can easily rule out false-positive alarms and combine AI-ready data pipelines for predictive maintenance. Shifting from reactive to proactive asset management elevates operational efficiency and reliability for utility operators and their residential and commercial sectors.
Finally, with smart monitoring systems in place, utilities can remain compliant and easily generate audit-ready reports on all operational data, including performance, emissions, and generation metrics. Reports from live telemetry can be easily accessible when regulators or investors request operational data. This also ensures transparency and accountability in operational practices.