NERC and ERCOT Compliance for Natural Gas Power Plants

A GO/GOP guide to the O&P Reliability Standards, the ERCOT Nodal Operating Guide and GADS reporting

Executive Summary

A new natural gas plant in ERCOT becomes subject to two regulatory systems at once. As a registered Generator Owner (GO) and Generator Operator (GOP), it must meet the NERC Reliability Standards enforced by Texas RE. As an ERCOT Resource, it must also meet the ERCOT Protocols, the Nodal Operating Guide, the Planning Guide and the PUCT's weather-preparedness rule. The two overlap, they change on different schedules, and they are audited by different bodies.



This guide sets out, standard by standard, what a gas-fired GO/GOP in ERCOT has to comply with today, what changes between now and 2029, and what does not apply. It explains where the engineering evidence comes from and how GADS reporting works for plants built from many smaller units. The applicability screen is taken directly from the NERC US Effective Date Status / Functional Applicability matrix, and the ERCOT items are checked against ERCOT's published revision requests.

Key points

• Compliance starts on the day of registration, not later. Texas RE expects a newly registered generator to be audit-ready from day one, so the program has to be built before commercial operation.
• Much of the evidence is engineering rather than paperwork. Protection settings, Facility Ratings, capability tests and dynamic models make up the evidence for PRC, FAC, MOD and VAR requirements.
• The ERCOT and NERC obligations cover the same equipment. Governors, AVRs, voltage control and cold weather each appear in both rulebooks and should be managed as one obligation.
• The number of units multiplies the workload. A plant made of twenty-plus engines has twenty-plus sets of settings, maintenance records and notifications.
  

1. How Compliance Is Layered for an ERCOT Gas Plant

Four bodies set or enforce the rules that apply to a gas-fired generator in the ERCOT Interconnection. Knowing which one owns a given requirement tells you who audits it, how a violation is handled and where the current text lives.

For ERCOT, the NERC Reliability Coordinator, Balancing Authority, Transmission Operator and Planning Coordinator functions are largely performed by ERCOT itself. When a standard says "provide data to the Transmission Operator" or "follow the Reliability Coordinator's Operating Instructions", in practice the counterparty is ERCOT, usually reached through the plant's QSE.

Figure 1 — Illustrative one-line of a multi-engine gas plant, showing where the main O&P standards and ERCOT requirements apply. Composite example for explanation only.

2. What Registration as GO and GOP Actually Commits You To

The Generator Owner owns the physical equipment and the engineering facts about it: ratings, protection settings, models, maintenance and design basis. The Generator Operator runs the plant in real time: it takes instructions, communicates, reports status changes and trains operators. One company often holds both registrations, but the obligations stay separate and are audited separately.

"Audit-ready on the day it is registered"

Texas RE's guidance for new generator entities is blunt: the entity should be audit-ready on the day it is registered, and it should allow six to twelve months to prepare. Every applicable requirement needs an owner, a procedure, a control and evidence from the registration date. The first self-certifications typically follow within about two years. A program built after commercial operation starts with a backlog of potential noncompliance.

3. The 32 NERC O&P Standards That Apply Today

The list below comes from filtering the NERC applicability matrix to standards that are Mandatory Subject to Enforcement, and keeping each standard version that has at least one requirement flagged for GO or GOP. CIP cyber security, NUC-001, non-ERCOT regional standards and inverter-based resource standards were then removed; Section 5 explains why. "Conditional" means the standard applies only if a plant-specific fact is true.

What resolves the conditional standards

At a 230 kV or 345 kV point of interconnection, TPL-007 and PRC-023 are usually live. The GSUs will almost always have wye-grounded high-voltage windings above 200 kV, and a gen-tie at that voltage normally carries load-responsive protection.

4. What Changes Between Now and 2029

Six approved future versions affect a gas-fired GO/GOP. None is a new obligation class, but each one requires procedures, data matrices or settings evidence to be revised before its effective date.

Standards on the way out

PRC-017-1 (RAS maintenance and testing) shows an inactive date of 31 March 2027 in the NERC matrix, and MOD-026-1 has already been replaced by MOD-026-2, which consolidates generator model verification with its GO requirements phasing in from 2027. A program should record these transitions explicitly, so that an auditor can see which version applied on any given date.

5. What Does Not Apply to a Gas Plant — and Why

An applicability determination is only defensible if it also records what was excluded and why. For a synchronous gas plant in ERCOT, the usual exclusions are:

How to read the NERC matrix correctly

• Filter on status first. Only "Mandatory Subject to Enforcement" and "Subject to Future Enforcement" matter. Inactive versions make up most of the rows.
• Aggregate to the standard version. Applicability flags sit on individual requirements and parts. A version applies to a GO if any requirement is flagged GO.
• Ignore the second-category columns for a synchronous plant. The GO-2 and GOP-2 columns relate to the newer inverter-based registration categories.
• Record effective and inactive dates. That shows which version governed on any audit date.
  

6. The ERCOT Layer: Nodal Operating Guide Requirements for Gas Plants

ERCOT's operating requirements for generators are in the Nodal Operating Guide (NOG), and they change through Nodal Operating Guide Revision Requests (NOGRRs). Many NOGRRs were written to align ERCOT practice with a NERC standard, so the two rulebooks track each other closely. They are not identical, however, and ERCOT's versions are often more specific about test procedures, set points and reporting windows. The table groups the requirements that apply to a natural gas Generation Resource into 20 compliance areas.

Nodal Operating Guide Section 2 at a glance

For a generator, the core of Section 2 is: 2.2.5 Automatic Voltage Regulators, 2.2.6 Power System Stabilizers, 2.2.7 Turbine Speed Governors, 2.2.8 Performance/Disturbance/Compliance Analysis, 2.2.10 response-time requirements, 2.4 outage coordination, 2.6 under/over-frequency relaying, and 2.7 voltage profile and operational voltage control. Section 2.7.3.5 sets out Resource Entity responsibilities. Section 6 covers disturbance monitoring and protective relaying, Section 7 telemetry and communications, Section 9 monitoring programs, and the Section 8 attachments carry the test procedures: 8C governor speed tests, 8D seasonal net capability verification, 8H alternative fuel capability and 8J primary frequency response measurement.

7. Where NERC and ERCOT Meet: Five Engineering Deep Dives

7.1 Governors and primary frequency response

BAL-001-TRE-2 is the Texas RE regional standard for primary frequency response, and NOG Section 2.2.7 and Attachments 8C and 8J carry ERCOT's governor requirements and measurement methods. Together they require that governors be in service, not blocked or limited by plant controls, set to ERCOT's droop and deadband performance, and able to deliver sustained response.

For an engine plant, the evidence is unit by unit. Each engine needs a record of its governor settings and in-service status. Each qualifying frequency event needs a performance review showing the plant's initial and sustained response. The most common gap is a plant-level controller that pulls output back to its MW set point after the governor responds, which defeats sustained response even though every governor is set correctly.

7.2 Voltage control: AVR, PSS and the tolerance band

VAR-002-4.1 requires the GOP to run the AVR in automatic voltage control mode, maintain the voltage schedule and report status changes. ERCOT adds the operational detail: NOG 2.2.5 for AVRs, 2.2.6 for PSS, 2.7.3 for voltage set points and Resource Entity duties. NOGRR195 set the generator voltage control tolerance band, effective 5 February 2021.

With 24 AVRs, the 30-minute notification is the requirement most likely to be missed. Operators need a single, simple trigger for example, any AVR alarm on the plant controller means a call to the QSE and a log entry rather than a judgement call at 3 a.m.

7.3 The protection-settings trio: PRC-019, PRC-024 and PRC-025

These three standards all test generator protection and control settings against a different boundary:

• PRC-019-2 checks that voltage regulating controls and limiters coordinate with unit capability and protection, so that the AVR limiters act before protection trips the unit. It must be reviewed at least every five years and within 90 days of a qualifying change.
• PRC-024-3 (PRC-024-4 from 1 October 2026) checks that frequency and voltage protection does not trip the unit inside the no-trip zones. This includes auxiliary-system protection that can take a unit offline. NOG 2.6 adds ERCOT's under- and over-frequency set-point requirements.
• PRC-025-2 checks that load-responsive protection on the generator, GSU and unit auxiliary transformers will not trip at the loadability levels in Attachment 1.

The settings are the same, but the three pass/fail tests are different, so one settings database should drive all three evidence packages. PRC-005-6 then requires every protection component — relays, CTs and VTs, station DC supply, communications and control circuitry, and sudden pressure relays on the GSUs to be maintained at the intervals in its tables. On a multi-engine plant, that inventory runs to hundreds of components.

7.4 Capability, ratings and models

• FAC-008-5 requires a documented Facility Ratings methodology and ratings for every element up to the POI, set by the most limiting series component. At 230 kV and 345 kV, the most limiting element is often a disconnect switch, a jumper or a CT ratio rather than the transformer.
• MOD-025-2 verifies real and reactive capability within 12 months of commercial operation and every five years after. ERCOT's reactive capability testing (NOG 3.3.2, NOGRR147) should be run in the same campaign.
• MOD-026-2 verifies the excitation, governor and plant-control models against field behavior. ERCOT's Planning Guide model-quality requirements (PGRR075, PGRR085, PGRR102) require that model parameters match field settings.
• MOD-032-1 provides the steady-state, dynamic and short-circuit data that ERCOT's planning models use. MOD-032-2 takes over from 1 April 2028.

7.5 Cold weather: EOP-012-3 and PUCT §25.55 together

Since Winter Storm Uri, cold weather has been regulated twice over: by NERC through EOP-012-3 and by the PUCT through 16 TAC §25.55. A single weatherization program can satisfy both, but only if it is designed against both.

8. GADS, MIDAS and Cold Weather Data Reporting

8.1 What GADS requires

Under NERC's Section 1600 data request, any GO on the NERC Compliance Registry must report to the Generating Availability Data System for conventional units with a nameplate capacity of 20 MW or greater, and has had to since 1 January 2013. The 2026 GADS Data Reporting Instructions set out the details.

• Design data must be submitted before any event or performance data. The expanded design data set introduced in 2024 applies.
• Event data (outages, derates and reserve shutdowns) and performance data (hours, generation, starts) are due within 45 days after the end of each calendar quarter.
• Reciprocating engines have their own event-reporting row and cause codes. Since 2024, each event also carries a mandatory Contributing Operating Condition code, which includes cold weather, hot weather and ice or snow.
• Data is submitted to NERC's GADS reporting application through the OATI-hosted NERC webPortal.

8.2 The reciprocating-engine sizing problem



Large engine plants are built from many units of around 18 to 19 MW each, just below the 20 MW threshold. The GADS Data Reporting Instructions address this in two ways. First, where several engines and generators are combined, the group may be reported as a single unit or as individual units. Second, units that share an electric meter are treated as one "miscellaneous" unit sized by the group — and a group of 20 MW or more is mandatory to report.

8.3 The other two data requests

• MIDAS: a quarterly Section 1600 data request for Protection System misoperations. It applies to GOs that own BES Protection Systems and links directly to PRC-004-6.
• Cold Weather data: an annual Section 1600 submission from every registered GO, covering Extreme Cold Weather Temperatures, Corrective Action Plans and operating constraints. It is tied to EOP-012.
  

9. What Commonly Gets Misstated

Summaries of ERCOT and NERC requirements in circulation including machine-generated ones often contain errors that would put a compliance program on the wrong footing. These are the ones that come up most often for gas plants, checked against the primary source.

10. The Compliance Calendar

Most violations at generator entities happen on a date a missed notification window, a lapsed maintenance interval or a late submission not in a missing procedure. A plant's calendar should contain at least the following.

11. Composite Case Study: A 24-Engine Gas Plant in ERCOT

Plant

The illustrative plant has twenty-four 18.9 MW gas engine-generator sets in eight groups of three, each group on a three-winding step-up transformer. A 345 kV switchyard and a short overhead gen-tie connect it to the POI. It is gas only, simple cycle, and registered as GO and GOP, with a third-party QSE.

Applicability outcome

• All 21 "Applies" standards were confirmed.
• Of the 11 conditional standards, TPL-007-4 and PRC-023-6 applied because of the 345 kV wye-grounded GSU windings and the gen-tie protection. PRC-027-1 applied at the TO interface.
• EOP-005, PRC-012 and PRC-017 were documented as not applicable after written confirmation that the plant was not a Blackstart Resource and had no RAS.
• FAC-003-5 was screened out on gen-tie length, and the determination was recorded.

What the gap assessment found

None of these findings was a paperwork problem. Each one was an engineering fact that the compliance evidence exposed. That is typical: the program finds its value in the settings, ratings and controls, not in the binders.

12. Building the Program: An Eleven-Step Method

1. Kickoff and data collection: one-lines, settings, OEM data, transformer tests, interconnection agreement, ERCOT registration data.
2. Requirement-level applicability matrix, with each conditional item resolved and each requirement assigned to GO, GOP, QSE or contractor.
3. Gap assessment of design, settings and planned O&M practice against every applicable requirement.
4. Compliance program manual: governance, internal controls, evidence management, change management and noncompliance handling.
5. Standard-specific procedures and plans, typically about 25 controlled documents for a gas GO/GOP.
6. Technical evidence review: PRC-019, PRC-024 and PRC-025 settings, FAC-008 ratings, MOD-025 and MOD-026 plans, VAR-002 data and EOP-012 design.
7. ERCOT compliance procedures for the 20 NOG areas, integrated with the NERC matrix.
8. Evidence binders structured to the NERC Reliability Standard Audit Worksheets (RSAWs).
9. A compliance calendar with owners and reminders.
10. Role-based training for operators, engineers and management.
11. A readiness review (mock audit) before registration or commercial operation.

Then, every quarter

Calendar management, evidence validation, regulatory change tracking across NERC, Texas RE, ERCOT and the PUCT, event and misoperation support, data-request responses, GADS and MIDAS submittals, and a quarterly status report. Each year: an internal compliance assessment, a procedure review, refresher training and weather-preparedness support ahead of 1 December and 1 June.

13. How Keentel Engineering Helps

Keentel Engineering combines NERC O&P compliance with the power system, protection and interconnection engineering that produces the evidence. For natural gas plants in ERCOT, that means one team can write the program, review the settings and ratings behind it, and keep it current.

14. Frequently Asked Questions

References and Further Reading

NERC

• NERC, US Reliability Standards and Effective Date Status / Functional Applicability
• NERC, 2026 GADS Data Reporting Instructions
• NERC, Cold Weather Section 1600 Data Reporting Instructions
• NERC, MIDAS Section 1600 Data Request

Texas RE

• Texas RE, Generator Welcome Package
• Texas RE, Registration

ERCOT and PUCT



• ERCOT, Current Nodal Operating Guide
• ERCOT, revision request pages — NOGRR111, 139, 143, 147, 150, 167, 169, 174, 195, 199, 255, 283, 287
• ERCOT, NPRR1108, NPRR1120, NPRR1309
• ERCOT, Weatherization Trending Topic 
• PUCT, 16 TAC §25.55 Weather Emergency Preparedness

Links were current as of September 2026.

Disclaimer

Educational purpose. This guide is general technical information for engineers, owners and operators. It is not legal advice, and it is not a compliance determination for any specific facility.

Applicability. Applicability depends on registration, plant configuration and regulator determinations. Standards, ERCOT rules and PUCT rules change; always confirm against the current text and effective dates before relying on this guide.

Composite examples. Case studies and illustrative configurations are composites built for explanation. They do not describe any specific client, site, project, owner, manufacturer or utility.



No warranty. Keentel Engineering makes no warranty, express or implied, as to the completeness or fitness for purpose of this information and accepts no liability for decisions made in reliance on it.

Trademarks and non-affiliation. NERC, ERCOT, Texas RE, PUCT, OATI and other names are marks of their respective owners. Their use does not imply affiliation with or endorsement of Keentel Engineering.