Grid Compliance Strategies for Power System Resilience

"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

Grid-forming control to achieve a 100% power electronics interfaced power transmission systems by Taoufik Qoria -”Nouvelles lois de contrˆole pour former des r´eseaux de transport avec 100% d’´electronique de puissance” ´ECOLE DOCTORALE SCIENCES ET M´ETIERS DE L’ING´ENIEUR L2EP - Campus de Lille  Abstract: The rapid development of intermittent renewable generation and HVDC links yields an important increase of the penetration rate of power electronic converters in the transmission systems. Today, power converters have the main function of injecting power into the main grid, while relying on synchronous machines that guaranty all system needs. This operation mode of power converters is called "Grid-following". Grid-following converters have several limitations: their inability to operate in a standalone mode, their stability issues under weak-grids and faulty conditions and their negative side effect on the system inertia.To meet these challenges, the grid-forming control is a good solution to respond to the system needs and allow a stable and safe operation of power system with high penetration rate of power electronic converters, up to a 100%. Firstly, three grid-forming control strategies are proposed to guarantee four main features: voltage control, power control, inertia emulation and frequency support. The system dynamics and robustness based on each control have been analyzed and discussed. Then, depending on the converter topology, the connection with the AC grid may require additional filters and control loops. In this thesis, two converter topologies have been considered (2-Level VSC and VSC-MMC) and the implementation associated with each one has been discussed. Finally, the questions of the grid-forming converters protection against overcurrent and their post-fault synchronization have been investigated, and then a hybrid current limitation and resynchronization algorithms have been proposed to enhance the transient stability of the system. At the end, an experimental test bench has been developed to confirm the theoretical approach.  VIEW FULL THESIS: https://lnkd.in/dcTJU-9v

🔌 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

Kauai nearly learned the hard way what “IBR grid physics” really means. In 2021, an island grid with rising inverter penetration saw a system oscillation after a large unit tripped; the unit was supplying ~60.6% of system load (a severe N−1). System frequency didn’t just dip, it rang for ~60 seconds, with a reported 18–20 Hz with a reported 18–20 Hz oscillatory mode superimposed (well above classical electromechanical swing frequencies). The response wasn’t “add more spinning mass.” It was control engineering, in three steps: • identify the inverter interactions behind the oscillation • validate with high-fidelity EMT + hardware-grade testing • then shift the control behaviour, with grid-forming operation later observed to mitigate the oscillations. The bigger point is this: Stability is becoming a measurable, engineerable grid commodity, not something we historically inherited by default from synchronous machines being online. And once you accept that, a lot changes: • connection requirements: “model + settings + performance envelope”, not just MW/Mvar • model validation expectations: EMT credibility becomes a gate, not a nice-to-have • what operators need visibility over: control modes, limits, and fast transitions become operational signals • how we specify (and procure) grid services: “energy” and “capacity” aren’t enough, we start buying damping, fast frequency response, and voltage support as products The question isn’t whether inverters can provide “strength”. It’s whether our planning, compliance, and operational frameworks are ready to treat stability like a first-class product. 👉 Will we end up requiring grid-forming capability for every new large inverter-based solar or battery plant, or only where the grid is already weak? Figure is an illustrative reconstruction (not measured data). Source for the underlying event is in the first comment. #PowerSystems #GridStability #InverterBasedResources #GridForming #EMT #SystemStrength #FrequencyStability #GridCodes

For TSOs, the energy transition has moved decisively from strategy to execution. Recent expert discussions on grid reliability highlighted a reality every system operator now faces: power systems are being operated closer to their physical limits, with less inertia, higher volatility, and far greater uncertainty than legacy planning frameworks were designed to manage. In this environment, deterministic capacity limits and offline security studies are no longer sufficient. Executives need operational answers in real time: How much load can the grid safely carry right now? For how long? And with what confidence level? This is why probabilistic, real-time prediction of load and network capacity is becoming a core operational capability. It allows operators to replace conservative static margins with quantified risk, enabling higher asset utilisation, reduced congestion costs, and safer integration of renewables — without compromising security of supply. This shift is not optional. Under the EU regulatory framework led by ACER, advanced probabilistic and real-time approaches to capacity calculation and operational security become mandatory by end-2027. Compliance will be assessed not on intent, but on demonstrable operational capability. For TSO leadership, the message is clear: • Reliability is now a probabilistic outcome, not a deterministic assumption • Regulatory compliance and real-time operations are converging • Competitive advantage will accrue to operators who can safely run closer to true system limits The question is no longer whether probabilistic real-time capacity forecasting will be adopted — but who will be ready in time.

🔴 A single transmission fault in Ireland caused 387 MW of data center load to vanish in milliseconds. 52% of total data center demand — gone — because UPS systems switched to backup instead of riding through the fault. EirGrid's worst-case analysis: the resulting imbalance could exceed 1,150 MW. More than double what the system was designed to handle. This isn't just an Irish problem. Similar events have been observed in the US, and TSOs across Europe are waking up to the same risk. The current EU Demand Connection Code (DCC) was not designed with hundreds of MW of power-electronic-interfaced loads in mind. That's changing. The upcoming DCC revision is expected to introduce stricter requirements for large demand facilities, and several TSOs are already moving ahead nationally. The types of requirements being discussed: → Fault Ride-Through: Remain connected during voltage dips caused by transmission faults, instead of tripping to backup → RoCoF Withstand: Tolerate rapid frequency changes without disconnecting → Post-Fault Active Power Recovery: Restore consumption within defined timeframes after fault clearance to avoid worsening the imbalance → Reactive Power Capability: Maintain power factor obligations at the connection point → Remote Disconnection & Demand Response: Enable TSOs to remotely curtail or disconnect facilities during grid emergencies → Frequency & Voltage Withstand: Operate continuously across extended frequency and voltage ranges EirGrid (Ireland) is leading with explicit grid code modifications. Other TSOs are developing their own frameworks. In the US, NERC has issued a Level 2 Alert on large load risks. The direction of travel is clear — but most European TSOs have not yet implemented specific requirements. The real question: 𝗜𝘀 𝘁𝗵𝗲 𝘁𝗲𝗰𝗵𝗻𝗶𝗰𝗮𝗹 𝗺𝗮𝘁𝘂𝗿𝗶𝘁𝘆 𝗮𝗰𝘁𝘂𝗮𝗹𝗹𝘆 𝘁𝗵𝗲𝗿𝗲? Data center architectures were designed for uptime — not grid compliance. UPS and rectifiers were never built to ride through transmission faults. Manufacturers are working on solutions. But is the market ready yet with the compliance cost remaining a major unknown? 𝗪𝗶𝗹𝗹 𝘁𝗵𝗲𝘀𝗲 𝗲𝗺𝗲𝗿𝗴𝗶𝗻𝗴 𝗿𝗲𝗾𝘂𝗶𝗿𝗲𝗺𝗲𝗻𝘁𝘀 (in addition to limited grid capacity) 𝗽𝘂𝘀𝗵 𝗱𝗮𝘁𝗮 𝗰𝗲𝗻𝘁𝗲𝗿𝘀 𝘁𝗼 𝗴𝗼 𝗼𝗳𝗳-𝗴𝗿𝗶𝗱 𝗮𝗻𝗱 𝗯𝘂𝗶𝗹𝗱 𝘁𝗵𝗲𝗶𝗿 𝗼𝘄𝗻 𝗺𝗶𝗰𝗿𝗼𝗴𝗿𝗶𝗱? If compliance costs become prohibitive, hyperscalers might find it cheaper to go behind-the-meter — gas turbines, SMRs, BESS — and operate islanded. But losing hundreds of MW of controllable demand makes the grid harder to balance, not easier. What's your take — grid allies or going their own way? #GridStability #DataCenters #PowerSystems #FaultRideThrough #GridCode #EnergyTransition #TSO #Microgrids

⚖️🔧⚡ Transitioning from Grid-Following (GFL) to Grid-Forming (GFM) in Solar + BESS Projects As more renewable projects move toward grid-forming capabilities, it’s critical to understand that success depends on two distinct but equally important layers: 👉 Power Electronics (device level) 👉 GPM – Grid Performance Management (plant/system level) They solve different parts of the problem — and both must evolve together. 🔌 1. Power Electronics – The Foundation Before (GFL): -Inverters follow grid voltage & frequency (PLL-based) -Require a strong grid -Limited stability support (no inertia, -weak voltage control) After (GFM): -Inverters create voltage & frequency -Act like synchronous machines (virtual inertia, droop control) -Operate in weak grids or islanded mode 🔧 Key Changes: Control shift: PLL → Droop / Virtual Synchronous Machine (VSM) Add: Frequency droop (P–f) Voltage droop (Q–V) Synthetic inertia OEM firmware & protection updates (e.g., Sungrow, Tesla, SMA) Integration of BESS for fast dynamic support Enhanced fault response & ride-through capability 🧠 2. GPM – The System-Level Brain GPM coordinates the entire plant: Inverters BESS Plant Power Controller (PPC) Interfaces with utilities (e.g., Oncor) and ISOs (e.g., ERCOT) 🔧 What Changes with GFM: ✔ PPC Upgrades Grid-forming dispatch Multi-unit coordination Voltage & frequency reference control Black start capability ✔ EMS Enhancements BESS dispatch optimization SOC management (maintain headroom for grid support) ✔ Grid Compliance Meet requirements like NOGRR272 Fast frequency response Voltage ride-through Disturbance support ✔ Protection Updates Adaptive protection schemes Revised relay coordination Anti-islanding updates ✔ Operational Modes Grid-connected ↔ Grid-forming Grid-forming ↔ Islanded Black start sequences ⚖️ Power Electronics vs GPM – Key Difference Power Electronics: Creates voltage & frequency (device-level stability) GPM: Coordinates and sustains plant-wide performance ⚡ Real Example: 40 MW Solar + 10 MW / 20 MWh BESS Without GFM: PV becomes unstable in weak grids No meaningful frequency support With GFM: BESS + inverter form the grid Stabilize voltage & frequency GPM ensures: SOC ~50–70% (bidirectional support) Dynamic dispatch Alignment with ERCOT signals 🚧 Key Risks if Not Done Right Control instability (oscillations) BESS depletion → loss of support Protection miscoordination Non-compliance (e.g., NOGRR272) Interconnection delays ✅ Bottom Line ⚡ Power Electronics = “Can we form the grid?” 🧠 GPM = “Can we control it reliably at scale?” 👉 You need both: Power electronics enables the capability GPM ensures it works in real-world grid conditions #SolarEnergy #RenewableEnergy #EnergyStorage #BESS #GridForming #GridFollowing #PowerElectronics #EnergyTransition #ERCOT #GridStability #CleanEnergy #Inverters #Engineering #PowerSystems #EnergyManagement #UtilityScale #SolarProjects #Transmission #Infrastructure