A Coordinated Electric System Interconnection Review—the utility’s deep-dive on technical and cost impacts of your project.

Challenge: Frequent false tripping using conventional electromechanical relays
Solution: SEL-487E integration with multi-terminal differential protection and dynamic inrush restraint
Result: 90% reduction in false trips, saving over $250,000 in downtime

ERCOT requires that all IBRs maximize their frequency ride-through capability to the fullest extent possible. This includes:

Updating software, firmware, settings, and parameterization.
Reporting changes made and the date of implementation.
Attesting whether further physical equipment modifications were made.
Submission of a frequency ride-through curve (0–600 seconds) to demonstrate compliance with Nodal Operating Guide (NOG) Section 2.6.2.1.

Operators must also confirm their ability to meet the minimum ride-through standards in effect as of May 1, 2024, and submit an Initial Frequency Ride-Through Capability Report if they fall short.

Similar to frequency, the voltage ride-through requirement compels resources to optimize software and equipment settings. Operators must:

Certify that their settings are maximized.
Submit voltage ride-through capability curves, including overvoltage behavior for IEEE 2800-2022-compliant resources.
Confirm compliance with NOG Sections 2.9.1.1 and 2.9.1.2, or submit the Initial Voltage Ride-Through Capability Report.

Technical validations also include evaluations of phase angle jumps, over-voltage protection time delays, and whether rate-of-change measurements could trigger a trip.

For operators navigating ERCOT NOGRR-245 compliance, early preparation is critical. Data accuracy, OEM coordination, and proper formatting in the DocuSign template can determine whether ERCOT accepts your submission without delays. Missing technical data, providing generic ride-through information, or failing to reflect Point of Interconnection performance are common causes for rejection. If you’re unsure about your submission readiness, our ERCOT NOGRR245 Compliance Services can help you complete every step—from capability modeling to exemption form preparation.

Does NOGRR245 apply to Type 3 wind projects undergoing repower?
Yes. Type 3 WGRs are considered inverter-based resources (IBRs). If modifications under Planning Guide Sec. 5.2.1(1)(c) are fully implemented by 1/1/2028, they only need to meet NOG 2.9.1.2 VRT requirements but must still maximize capability. If not completed by 1/1/2028, NOG 2.9.1.1 applies.
Does NOGRR245 apply to my solar PV project (Type 1 IBR)?
Yes. Type 1 PV projects are considered IBRs under ERCOT’s definitions and are subject to the same requirements.
What is the difference between Type 1, 2, and 3 WGRs?
Type 1: Directly-connected induction generators (not IBRs)
Type 2: Induction generators with external resistance (not IBRs)
Type 3: Doubly fed induction generators (considered IBRs)
What Resources are subject to NOGRR245?
All IBRs, Type 1 and Type 2 WGRs, regardless of SGIA date, must comply with the relevant sections of the NOG and IEEE 2800-2022, and maximize performance consistent with Good Utility Practice.

When must models be updated to reflect NOGRR245 requirements?
Updates submitted after 10/1/2024 must include model quality tests per DWG Procedure Manual Section 3.1.5.
What tests or simulations are required to demonstrate compliance?
While ERCOT does not require specific simulations for every requirement, submitted models must accurately reflect actual or anticipated plant performance. Simulation-based validations are recommended but not strictly mandated.
What models must be submitted by 4/1/2025 if filing IFRTCR or IVRTCR?
Pre- and post-maximization versions of PSSE, TSAT, and PSCAD (if applicable). PSCAD is not required unless it was previously mandated.
Do balance-of-plant relays need to be modeled?
Yes, if they affect ride-through performance during system disturbances.

What is due by April 1, 2025?
• Submit IFRTCR or IVRTCR if your Resource cannot meet the respective NOG requirements by 12/31/25.
• Request extensions or exemptions as needed per Section 2.12.
What must be completed by December 31, 2025?
Maximize FRT and VRT settings
Meet applicable IEEE 2800-2022 Sections 5, 7, and 9
Submit all accurate models and performance attestations
What happens if a project fails to complete modifications by 1/1/2028?
It must then comply with IEEE 2800-2022 full performance requirements and NOG 2.9.1.1, losing eligibility for legacy exceptions.

If my project has an SGIA signed before 8/1/24 but amended after, which date applies?
The original SGIA date remains valid. Amendments do not reset compliance timelines.
Does meeting legacy requirements suffice for compliance before 2028?
Only if the project maximizes its ride-through capability. Minimum settings alone do not suffice.
For hybrid projects (solar + BESS), which test cases are required?
All relevant operational modes must be tested. At minimum, maximum injection and withdrawal scenarios are required.

In 1995, Sonny Patel earned his Electrical Engineering degree from the University of Illinois. But degrees don't build legacies — action does.

For three decades, he has worked the power industry from every side of the table: 16 years as a utility engineer at Exelon/Commonwealth Edison; generation leadership across hydroelectric, industrial steam turbine, and a 9 GW renewable fleet; NERC Regional Entity Senior Compliance Engineer and Audit Team Lead, auditing some of the nation's largest utilities; and testing and commissioning lead on equipment up to 765 kV — the very top of the North American grid.Utility. Generator. Regulator. Consultant. Few engineers have seen all four seats. Fewer still have sat in them.

His experience spans nuclear, hydro, conventional generation, renewables, oil and gas, mining — and today's data centers, where he is authoring a three-book series on data center design. He is a Licensed Professional Engineer in six states and a Licensed Electrical Contractor in Florida (Unlimited EC) — he doesn't just design the work; he's qualified to stand behind its execution.Today, as Founder and CEO of Keentel Engineering, Sonny leads a nationwide team of engineers delivering substation design, power system studies, NERC compliance, and commissioning — done right, coast to coast.Three decades. Every side of the table. One standard: accountable engineering.

In 1995, Sonny Patel earned his Electrical Engineering degree from the University of Illinois. But degrees don't build legacies — action does.

Utility. Generator. Regulator. Consultant. Few engineers have seen all four seats. Fewer still have sat in them.

Today, as Founder and CEO of Keentel Engineering, Sonny leads a nationwide team of engineers delivering substation design, power system studies, NERC compliance, and commissioning — done right, coast to coast.Three decades. Every side of the table. One standard: accountable engineering.