Deadline approaching to comply with new NERC regulations
By Brandon Ware, EverLine | The rapid growth of inverter-based resources (IBRs) — including solar PV, wind, battery energy storage systems (BESS), and hybrid generation — has fundamentally changed how reliability is managed on the North American Bulk Power System (BPS). In response, the Federal Energy Regulatory Commission (FERC) and the North American Electric Reliability Corp. (NERC) have closed a long-standing regulatory gap by requiring registration and compliance for a new class of BPS-connected resources known as Category 2 Inverter-Based Resources.
Based on the recent NERC guidance and FERC approvals, owners and operators of non-Bulk Electric System (non-BES) IBRs with an aggregate nameplate capacity greater than or equal to 20 MVA, connected through a system designed primarily for delivering such capacity to a common point at a voltage greater than or equal to 60 kV must register as Category 2 Generator Owners (GO) and Generator Operators (GOP). Full compliance with applicable reliability standards for these entities becomes mandatory by May 15, 2026, in many cases for the first time.
The 60 kV threshold marks a critical divide in electric power systems, separating distribution-level, localized operations from high-voltage, BES transmission practices. Adopting strict transmission-grade operating practices for infrastructure at or above this voltage is crucial for grid reliability, efficiency, and security.
The 2026 GO/GOP definition changes mark a pivotal shift in NERC regulation for Category 2 GO/GOP for IBRs, bringing previously exempt, smaller renewable energy assets under mandatory oversight to ensure grid reliability. The speed of the change, which has challenged grid planners, operators, protection engineers, and other facets of the electricity sector, is expected to deliver significant benefits for the BPS.
Compliance is mandatory with no exemptions, and includes strict modeling, data validation, and event reporting requirements. If multiple smaller facilities share a common point of connection and collectively meet the 20 MVA threshold at 60 kV or higher, all are considered Category 2 assets and must register.
How to get ahead of it
Being unprepared is costly and waiting until the 2026 deadline may create compliance gaps. For any IRB not yet registered, the time to act is now.
After reviewing all operating, under-construction, or late-stage development projects for NERC threshold compliance, each entity should establish an internal compliance program focused on data collection, modeling, and cybersecurity. Projects coming online, including those connecting in phases, should be registered early, even if only initial phases meet Category 2 thresholds. Failing to comply may result in operational risks, penalties, or forced curtailment by grid operators.
Adopt a TOP-certified mindset for a competitive advantage
NERC-Certified Transmission Operator (TOP) entities operate or direct the operation of BES transmission facilities. The certification process is difficult. The exam is highly technical, scenario-based, and covers complex power system operations, which often require extensive training and study to pass. Entities that receive TOP certification are recognized for managing complex power infrastructure, focusing on reliability and efficiency, and for incorporating smart technologies into the grid.
Given the challenges of certification, small operators should adopt a TOP-certified mindset for managing risk and maintaining system stability. Doing so shifts the focus from reactive maintenance to proactive, risk-aware, and secure, reliable operations that protect both infrastructure and business continuity while developing a competitive advantage for the entity. It requires anticipating issues before potential breaches or failures occur and creates an environment where compliance is built into daily routines. It also focuses on rigorous safety protocols and understanding the limits of equipment to prevent accidents and reduce unexpected downtime, as well as optimizing power flow to improve voltage stability and ensure reliable service to end customers.
By transitioning from transmission-grade practices to a TOP-certified mindset, entities are assured of the resilience and reliability needed to outperform competitors in the utility sector.
While adopting a NERC-certified mindset is optional, employing NERC-certified operators is mandatory and legally required to ensure the reliability of the BES in the United States and Canada. Personnel at the Reliability Coordinator, Balancing Authority, or Transmission Operator levels must be certified to maintain the safe and reliable operation of the power grid.
NERC enforces strict control room requirements, including data protection, personnel training, and secure communication links. Fortunately, organizations can access a fully staffed control room and strong compliance programs without building and staffing their own facility.
When to engage with experts
When a new or rapidly expanding IBR finds that internal resources are insufficient to manage the new, complex NERC registration, it may be most effective to outsource to specialized experts, especially when noncompliance threatens to hinder the renewable system.
A compliance specialist can support the development and implementation of a NERC compliance program and processes. A Control Center as a Service (CCaaS) significantly enhances compliance oversight by providing built-in tools for data protection and regulatory compliance. It starts with real-time, 24/7 monitoring, which is considered an essential compliance baseline. CCaaS also provides control and secure operations of critical utility infrastructure, specifically designed to meet NERC requirements.
Traditional, paper-based OEM/EPC binders need to be transitioned to an audit-ready, digital compliance system, which converts static documentation into a dynamic, “always-on” state of compliance. By facilitating a shift from manual, periodic monitoring to continuous, automated oversight, the IRB shifts from manual, reactive evidence gathering to proactive, immutable, and verifiable records that reduce audit duration and risk.
Proactive risk management provides immediate visibility into security postures, while quick threat detection helps reduce the risk of fines and reputational harm from delayed incident responses. The organized framework of policies, procedures, and monitoring allows operators to manage transmission, generation, and renewable assets while ensuring compliance with new NERC requirements by the deadline.
There are also new, comprehensive compliance management technologies that utilize verification protocols and distributed ledger technology to transform how compliance data is captured, verified, documented, and audited.
The best-case scenario is that technology will digitally capture and aggregate compliance requirements, location data, and operator qualifications to verify that the right work was performed on time, at the correct location, by a qualified operator before the record is stored. This verification process provides real-time compliance validation, reducing operational risk and giving confidence that an asset is audit-ready at any time.
Conclusion
Throughout 2024 and 2025, a significant portion of Inverter-Based Resources — approximately 14% to 16% of operational, materially impactful, non-BES IBRs — were not registered with NERC and, therefore, not subject to full NERC reliability standards. The significantly lower capacity thresholds designed to improve grid reliability have enveloped new, smaller, or grid-connected, non-BES resources. They are mandated to transition from a non-registered status to compliance by May 15, 2026.
Penalties for non-compliance are severe, including fines of up to $1.54 million per day per violation. Non-compliance can also result in mandatory mitigation plans, audits, and reputational damage. As NERC increases oversight of solar, wind, and storage, penalties for violating reliability standards, such as faulty modeling or failing to maintain required voltage or frequency controls, are strictly enforced.
Once it is determined that assets meet the new Category 2 GO/GOP criteria, IBRs must then file for registration, conduct a gap analysis, develop a compliance program, and train staff. It’s a hefty undertaking. Outsourcing is a means of avoiding significant resource strains and navigating the technical and regulatory hurdles associated with registration and compliance.
By partnering with a third party, IBRs can take advantage of 24×7 disturbance triage and documentation workflow for generating fleets. An outsourced resource can also help coordinate operations, communications, evidence capture, and follow-up actions, so owners aren’t improvising during an event. Talent bottlenecks are eliminated, and expert operator capabilities and training cultures de-risk startup timelines. By choosing a partner with a reputable SCADA Energy Management System (EMS) and Control Center operations tied to compliance programs and platform tooling, status, tasks, verification, and readiness can be built to run at a customizable scale.
Author info: Brandon Ware is VP Power O&M Services at EverLine Integrated Technical Services.
