Addressing Power Grid Reliability Concerns

"One of the key ways to make energy systems more reliable is by maximizing flexibility — improving how well the system can adapt in real time to changes in supply and demand. The more flexible the system, the better it can handle sudden demand spikes in the event of extreme weather, such as cold snaps or heat waves, or respond to supply disruptions such as plant outages. Improving flexibility includes upgrading aging infrastructure. Much of the U.S. grid was built decades ago under different demand patterns. Modernizing the grid — by updating substations and transmission equipment, deploying advanced sensors and incorporating advanced transmission technologies (ATTs), for example — can reduce failure rates during extreme heat and cold. These technologies help operators detect problems quicker, reroute power if equipment is damaged and restore service fast. Modernization not only improves reliability but also reduces expensive emergency interventions and lowers long-term maintenance costs. Increasing grid capacity, both through deployment of ATTs and building regional and interregional transmission lines, can reduce the risk of a local weather event turning into a widespread outage. Creating a more interconnected grid allows regions to share power during shortages. Having this greater transmission capacity also help keep prices down by allowing lower-cost electricity to reach areas facing higher demand. Demand-side management options can help ease pressure on the system during extreme weather events. These include encouraging customers and large users to reduce or shift electricity use during peak periods in exchange for lower bills or leveraging distributed energy resources to help prevent shortages. Systems that rely too much on a single fuel are more vulnerable to disruption. Diversification across energy sources and technologies helps reduce the risk of issues related to fuel shortages, infrastructure failures and localized weather impacts. Finally, policy is also critical. It’s vital that incentives are properly aligned with modern needs for flexibility and preparedness. This can help utilities make system investments that really work in extreme weather and minimize costs to consumers in both the short and the long run." Kelly Lefler World Resources Institute https://lnkd.in/e5syqXQp

A report by NERC warns that over half of North America faces a significant risk of energy shortfalls within the next 5-10 years due to surging electricity demand driven by data centers, electrification, and industrial growth. This increase, coupled with slow infrastructure development and accelerating generator retirements, creates a critical challenge for resource adequacy. Key findings from NERC’s 2024 Long-Term Reliability Assessment (LTRA) include: Demand Growth: Summer peak demand is projected to rise by 122 GW in the next decade, a 15.7% increase, while resource additions lag behind. Generator Retirements: Up to 115 GW of capacity may retire by 2034, with many retirements being replaced by variable generation sources. Regional Risks: MISO, SPP, New England, and Texas face elevated to high risks of energy shortfalls, particularly during extreme weather. Policy Needs: Industry leaders urge federal action to expedite infrastructure development, prioritize reliability, and address natural gas supply challenges. The report calls for urgent collaboration and policy shifts to ensure grid reliability and manage escalating demand effectively.

🔌 Grid operators are implementing various strategies to manage the declining inertia caused by the increased penetration of variable generation (VG) resources, such as wind and solar. These strategies fall into three main categories: maintaining inertia, providing more response time, and enhancing fast frequency response. To maintain inertia, operators can ensure that a mix of synchronous generators is online to exceed critical inertia levels. Additionally, synchronous renewable energy sources and synchronous condensers can be deployed to provide inertia. To provide more response time, operators can reduce contingency sizes and adjust underfrequency load shedding (UFLS) settings. Finally, enhancing fast frequency response involves leveraging load resources, extracting wind kinetic energy, and dispatching inverter-based resources to improve the grid's ability to respond to frequency changes. 🍃 Extracted wind kinetic energy refers to the capability of wind turbines to provide fast frequency response (FFR) by utilising the kinetic energy stored in their rotating blades. This approach can be particularly effective in addressing the challenges posed by declining inertia in power systems with high wind penetration. By extracting kinetic energy, wind turbines can respond rapidly to frequency deviations, thereby helping to stabilise the grid. This method can be used in conjunction with other resources to enhance overall system reliability and maintain frequency within acceptable limits. 💡 High deployment of variable generation (VG) resources can be effectively managed by combining extracted kinetic energy from wind turbines and increasing output from curtailed wind plants. The figure below illustrates that when these two strategies are combined, they significantly mitigate frequency decline. The simulation shows that relying solely on extracted kinetic energy results in frequency falling below UFLS (underfrequency load shedding), while using only FFR barely avoids UFLS. However, when both methods are applied together, the frequency decline is minimal, demonstrating that these approaches can serve as viable alternatives to traditional inertia and primary frequency response from conventional generators. #gridmodernization #stability #gridforming #powerelectronics #renewables #cleanenergy #solidstate

Yesterday, I spoke at the Federal Energy Regulatory Commission on behalf of the American Clean Power Association (ACP) about what it really takes to keep the grid reliable. Here’s the truth: You can’t fix resource adequacy in a vacuum. If we don’t solve interconnection bottlenecks, reform the transmission process, and update market signals—then capacity markets alone won’t save us. I shared four key messages: 1: Speed matters: New gas units take 5+ years to build. Meanwhile, renewable energy and storage projects already in the queue can be constructed as soon as 18–24 months.  Ignoring market-ready resources in the interconnection queue would be irresponsible. 2: Storage is dispatchable: It’s fast, flexible, and already keeping the lights on and —in places like Texas and California. We need to accredit it properly and remove outdated modeling assumptions. 3: Transmission is non-negotiable: Long-range and interregional lines are the cheapest, most reliable way to ensure we can meet load growth and integrate a balanced mix of resources. 4: Diversity is our insurance policy: No single resource is perfect. A reliable grid depends on a sufficient mix—solar, wind, storage, natural gas, (and where it makes sense nuclear, hydro and geo-thermal), demand-side tools, and yes, firm dispatchable power. It's not about picking winners; it's about building a resilient, flexible system. We’re not saying any one technology is perfect. But betting the grid on 20th-century tools won’t solve 21st-century problems. #CleanEnergy #GridReliability #FERC #EnergyStorage #Transmission #ResourceAdequacy #MarketsMatter #EnergyTransition https://lnkd.in/gt8fDMKW

Major Grid Failure in South-East Europe: A Wake-Up Call for Power System Resilience On June 21, 2024, a severe grid incident in South-East Europe triggered widespread blackouts across Albania, Bosnia & Herzegovina, Montenegro, and Croatia, disrupting the interconnected Continental Europe power system. What happened? 1. The failure began with a short circuit on two 400 kV transmission lines, caused by vegetation proximity, leading to cascading outages. 2. Within minutes, the voltage collapsed, causing the loss of 2,214 MW of generation and a major blackout. 3. The restoration process took nearly four hours, relying heavily on cross-border coordination. Key Lessons for Grid Stability: a. Vegetation Management Matters: Both initial short circuits were caused by inadequate clearance, highlighting the need for better maintenance policies. b. Real-Time System Awareness is Critical: The N-1 security analysis failed to detect voltage instability, underlining the need for improved dynamic monitoring. c. Resilience in High-Renewable Grids: Air conditioning demand accounted for 30-35% of total load, making voltage stability more vulnerable in heatwaves. d. Cross-Border Coordination is Essential: The top-down restoration strategy worked, but slow communication between TSOs delayed recovery. What’s Next? The report recommends: 1. Revising vegetation control policies near high-voltage lines 2. Enhancing real-time grid observability to predict voltage collapses 3. Optimising reactive power compensation to prevent instability 4. Fast-tracking digital grid technologies to improve response times The incident serves as a reminder that grid modernisation must go beyond adding renewable generation, it requires stronger transmission networks, real-time monitoring, and better cross-border coordination. Together with Prof. Aoife Foley, Chair in Net Zero Infrastructure at The University of Manchester, we are working to find innovative solutions to manage power system events like this as we move toward net-zero targets. What do you think? How can power systems better prepare for grid contingencies? #PowerSystems #GridStability #EnergyTransition #NetZero #Blackout #Transmission #GridResilience #VoltageStability

I'm seeing industrial operators and data centers commission feasibility studies that don't answer the right questions. And with NERC's 2025 Long-Term Reliability Assessment flagging 13 of 23 regions at resource adequacy risk through 2030, the stakes just got higher. MISO, PJM, Texas ERCOT, WECC-Northwest, WECC-Basin, SERC-Central. High-risk regions. The same regions where data center and industrial load growth is heaviest. That's not a coincidence. The grid reliability problem isn't just about capacity. It's about the type of capacity. Coal retirements are accelerating. Solar and batteries are coming online fast. But when you model dispatch during tight hours (winter peaks, extreme weather), the reliability attributes aren't the same as the baseload capacity they're replacing. Layer surging peak demand from data centers and electrification on top of that, and the gap widens between what the grid can reliably deliver and what industrial operators need to run 24/7. Which brings us to behind-the-meter generation and microgrids. Legal since the 1970s. What's changed: the economics now justify it as a competitiveness strategy, not just a resiliency backup. Most industrial teams commission a feasibility study. It comes back with a topline number: "Yes, on-site generation is possible. Here's the estimated cost." That's not enough. You need to know: • What's the optimal configuration for the best price per megawatt? • How does on-site generation compare to utility rates over 10+ years, including rate escalation? • Which combination of assets (gas, solar, battery, hybrid) delivers the best economics under high growth, low growth, and base case scenarios? • How does this hold up if fuel costs spike or equipment costs come in higher? Most feasibility studies don't model that. They give you a snapshot, not a stress test. In the microgrid space, we do feasibility analysis, but it's a techno-economical study. We model your load. Simulate multiple generation configurations. Run sensitivity analysis across different futures. Compare on-site vs. utility economics even if you already have grid access. The result: you know the optimal price per megawatt configuration and whether the economics hold up when the assumptions change. That's the difference between making an informed decision and hoping the utility can keep up. —— Evaluating behind-the-meter generation or microgrid solutions for your data center or industrial facility? Let's talk. I'll walk you through what a proper techno-economical study covers and what the numbers look like for your site. Grab time on my calendar or give me a call. 🗓️ https://t2m.io/mMoKxRy | 📱 1-888-218-6001 Image Source: NERC LTRA 2025

“Power Quality in the Age of Renewables” The power grid we know and rely on is changing. As renewable energy sources like solar and wind increasingly come online, the traditional balance of the grid is being tested. Power quality—once a fairly straightforward equation in stable, centralized systems—is now subject to a host of new challenges. Harmonic distortion, voltage fluctuations, and even transient instability are creeping in at levels that can disrupt sensitive industrial processes. For instance, variable frequency drives (VFDs), commonly used in modern manufacturing to enhance efficiency, are highly susceptible to harmonic interference. When left unchecked, harmonics can cause these drives to overheat, reduce equipment lifespan, and even trip critical systems offline. Similarly, the rise of distributed energy resources (DERs) often leads to voltage variability that standard equipment wasn’t designed to handle. Add in the increasing use of power electronics—like inverters—and you’ve got a cocktail of potential power quality headaches. So what’s the path forward? Next-generation power factor correction (PFC) technologies are stepping up to the challenge. Dynamic PFC systems that respond in real time to load changes, advanced harmonic filters (AHF), and voltage stability systems are becoming essential tools. Coupled with smarter, data-driven monitoring solutions, these advancements allow us to adapt to a grid that no longer behaves in the neat, predictable patterns of the past. As we transition to cleaner energy sources, understanding and mitigating these power quality issues is the key to keeping the lights on—not just literally, but also economically, as power disruptions can lead to costly downtime and equipment failure. #PowerQuality #ElectricalEngineering #RenewableEnergy #GridStability #HarmonicDistortion #EnergyEfficiency #PowerFactorCorrection #SustainableEnergy #IndustrialPower #VoltageControl #SmartGrid #CleanEnergy #GreenEnergy #EnergyManagement #ElectricalTesting #Transformers #ACBTesting #VoltageStability #PowerGrid #ElectricalMaintenance #TechSolutions #ResilienceEngineering #CarbonReduction #EnergyInnovation

Back to the grid…. Most people who use electricity don’t fully appreciate where it comes from or how the cost is calculated for them as a consumer. Energy spot price auctions are a mechanism used in electricity markets to price electricity according to real-time, market based supply and demand conditions at a particular moment. The goal of spot price auctions is to create a competitive market for electricity and facilitate efficient allocation of resources. However, the volatility in spot prices has created significant challenges for all stakeholders. The symptoms include price volatility and instability in electricity markets. To enhance grid reliability and stability, alternative approaches must be considered. While spot pricing may seem like a straightforward way to determine prices, it fails to account for the unique dynamics of the power grid and the long-term investments required to maintain a reliable and resilient energy ecosystem. The primary issue with spot price auctions is that they treat electricity as a commodity, subject to the whims of the market. Dramatic price fluctuations have severe consequences for both consumers and energy providers. When prices spike during periods of high demand or supply disruptions, it imposes enormous financial burdens on households and businesses, threatening economic stability. From the perspective of energy suppliers, the unpredictability of spot prices makes it challenging to plan for long-term capital investments in new generation capacity, transmission infrastructure, and grid modernization. These investments are crucial for ensuring the continued reliability and sustainability of the power grid, but they require a level of price certainty that spot markets simply cannot provide. It is time for policymakers and industry leaders to explore alternative pricing mechanisms that prioritize stability and long-term planning. One alternative is the use of capacity markets, where energy providers are compensated not only for the #electricity they generate but also for the availability of their generation assets. This model would provide a more reliable revenue stream for suppliers, enabling them to make the necessary investments in the grid's future. Another alternative is the implementation of forward contracts and hedging strategies. By locking in prices for electricity over longer time horizons, these mechanisms can help smooth out price volatility and provide the predictability that energy providers and consumers require. Transitioning to a more resilient energy system will not be easy, but it is a necessary step to ensure the long-term prosperity and security of our communities. By moving beyond the limitations of #energy spot price auctions, we can build a power grid that is truly fit for the future. The #grid of the future should reward a diverse portfolio of generation sources. It is time to move past demonizing reasonable energy sources even if they don’t fit certain ideologies.

Why the Grid You Rely On Costs More but Fails Less Almost every time there is a blackout or load shed of some kind, people point at the grid as being "unreliable." In my opinion, however, the case almost always is that it is incredibly well-designed and reliable, and just never intended to handle wide-area events like hurricanes and ice storms. How is the grid designed with reliability in mind? Since 2007, the transmission system in the U.S. has been required to comply with NERC regulations. Before that, utilities were allowed to design the grid as they saw fit or as the Public Utility Commission (PUC) allowed, as their grid investment expense was passed to the customer. Before 2007, you can find books and papers on probabilistic transmission planning, where utilities tried to determine the most reliability that could be added for the amount of money spent—the best "bang for the buck." After NERC shifted from a best practices organization to compliance-based, transmission planning became more focused on following strict guidelines rather than balancing cost and reliability. From a consumer's perspective, this increased their electrical bills, but it also introduced a more standardized method of planning the grid and expectations for contingency tolerance. Much of transmission planning now involves running N-1 contingency analysis (the grid loses one element—transmission line, transformer, capacitor bank, generator, etc.) and seeing how the grid is affected, designing projects that limit the impact and amount of load loss. This doesn't mean there won't be a loss of load, but it won't reach an "unacceptable amount of load loss" or cause cascading issues. In some cases, N-1-1 analysis is also performed to review how the grid will react to the effects of a second contingency before the first has been repaired, but after operators have had a chance to reconfigure the system. If there are stability issues, lines being overloaded, or voltages falling out of acceptable range, a project or mitigation is developed to alleviate these issues. Most transmission line projects focus on mitigating overloaded lines, often by reconductoring or bundling conductors to add capacity along corridors that make use of land already condemned for right-of-way. Voltage issues are often addressed with capacitor banks. Additionally, utilities are required to consider "extreme weather events" and effects from solar storms as part of NERC standards TPL-001 and TPL-007. These considerations, especially the latter, would not have received much attention before NERC compliance. The result is a grid that may not deliver the best "bang for the buck," but it is uniformly planned and has clear expectations for how it will operate under various conditions. There are hiccups that are being introduced to the grid as the result of non-dispatchable wind and solar generation being added but this separate from T&D itself. #utilities #renewables #energystorage #electricalengineering