An Introduction to Completing a NERC PRC-019-2 Study

For Synchronous and Distributed Generation Sources

PRESENTED BY: MATTHEW MANLEY

TEXAS A&M PROTECTIVE RELAYING CONFERENCE

MARCH 26-29 , 2018

Presentation Goals

Describe the PRC-019-2 reliability standard

Overview a typical synchronous generation PRC-019 study

Explain the impact of applying PRC-019 to include asynchronous generation facilities

Show an interpretation of how to demonstrate compliance for asynchronous generation facilities

Challenges and lessons learned

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NERC Reliability Standards

• Developed in response to the 2003 Northeast United States Blackout

• Goal to improve the performance and reliability of the bulk electric power system (BES)

• Compliance requirements are typically clearly defined

• Protection and Control (PRC)

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NERC PRC-019-2

◦PRC-019-2: Coordination of Generating Unit or Plant Capabilities, Voltage Regulating, Controls, and Protection

◦ Rev. 2 adopted by NERC board of trustees Nov. ’15

◦Purpose-“verify coordination of generating unit facility or synchronous condenser voltage regulating controls, limit functions, equipment capabilities and protection system settings.”

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PRC-019-2 Requirements

1.1.1“The in-service limiters are set to operate before the

Protection System of the applicable Facility in order to

avoid disconnecting the generator unnecessarily.”

R1 1.1.2 “The applicable in-

service Protection System devices are set to operate to

isolate or de-energize equipment in order to limit the extent of damage when operating conditions exceed

equipment capabilities or stability limits.”

R1 Resubmit PRC-019-2

documentation within 90 calendar days of applicable

equipment or setting change

R2

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Examples of Coordination Evidence

P-Q Diagram

R-X Diagram

Inverse Time Diagram

Equivalent tables

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Examples of Equipment Capabilities, Limiters, and Protection Functions

Field over-excitation

Inverter overcurrent

Field under-excitation

Generator reactive capabilities

Volts per hertz limiter and protection functions

Stator over-voltage protection

Generator volts per hertz capability

Transformer volts per hertz capability

Time vs. field current

Time vs. stator current

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Synchronous Generator Study Process

Facility Data

Collection

Data Review Plot Data

Mitigate Non-

Compliant Settings

Write Report

Describing Compliance

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Generator capability

Limiter settings

Protection settings

GSU & generator Volts/Hertz capabilities

Voltage regulation system manual

One and three line diagrams

Facility Data Required

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Compliant P-Q Plot

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Non-Compliant P-Q Plot

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Suggested Settings P-Q Plot

Final ReportAll conclusions from study in single, cohesive reportProgress from high-level summary to detailed discussionReport should assist in generating audit worksheetReport will have a range of audiencesDocument as-found and suggested settings if mitigation was necessary

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What about Asynchronous Generators?

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◦ Revision of the bulk electric power system (BES) definition◦ Includes dispersed generating facilities as applicable facilities

◦ NERC PRC-019 Revision 2◦ Addition of 4.2.3.1 identifies dispersed power producing resources, even where voltage

regulating control is performed solely at the individual generating unit is included as applicable facilities.

◦ What are typical Asynchronous Generators?◦ Solar PV◦ Wind Turbines (Type I, II, III, IV)

◦ Synchronous vs. Asynchronous Generators

Distributed or Asynchronous Generation Facilities

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Asynchronous Facility Analysis

Plant level controls

Combined Generators

Individual WTG

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WTG diagram

WTG characteristics

Rotor power output limit

Converter power output limit

Short and long time total power output limits

Main Breaker Protection Settings

GSU protection settings

Individual WTG Data

Type IWTGTCC

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Type III WTGTCC

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Combined Generator Analysis

Combined Generators

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One and three line diagrams

Feeder protection settings

Collector/GSU protection settings

VAR support protection settings

Capacitor bank ratings

Combined WTG Data

Collector & GSUTCC

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Plant Level Control Analysis

Plant level controls

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VAR Control Schemes

VAR Control Region(If MW Output > 4.0)

Capacitors Online If Power Flow Is > 30 MW

First Bank Switched In When Real Power Flow > 45 MW)

Second Bank Switched In When Power Flow > 70MW

125% p.u.

70.3% p.u.

Line Relays Trip GSU Offline

0% p.u.

Capacitors Tripped Offline

WTG Trip Offline 120% p.u.

High Voltage Control (Trip Caps While In Band)

110% p.u.

Deadband

1.2 p.u.

0.9 p.u.

Feeder & GSU Short Time Overvoltage Trip

Capacitor Undervoltage Trip

1.15 p.u.

Cap Bank, Feeder, & GSU Long Time Overvoltage Trip

1.1 p.u.

1.01 p.u.

0.99 p.u.

Slow Voltage Control Region

Slow Voltage Control Region

1.045 p.u.

0.955 p.u.

0.8 p.u.

0.5 p.u.

Fast Voltage Control Region

Feeder Undervoltage Trip

Fast Voltage Control RegionWTG Long Time Overvoltage Trip

WTG Medium TimeOvervoltage Trip

WTG Short TimeOvervoltage Trip

WTG Inst TimeOvervoltage Trip

1.25 p.u.

Voltage ControlPower Flow Control

Deadband

1.2 p.u.

0.9 p.u.

Feeder & GSU Short Time Overvoltage Trip

Capacitor Undervoltage Trip

1.15 p.u.

Cap Bank, Feeder, & GSU Long Time Overvoltage Trip

1.1 p.u.

1.01 p.u.

0.99 p.u.

Slow Voltage Control Region

Slow Voltage Control Region

1.045 p.u.

0.955 p.u.

0.8 p.u.

0.5 p.u.

Fast Voltage Control Region

Feeder Undervoltage Trip

Fast Voltage Control Region

WTG Long Time Overvoltage Trip

WTG Medium TimeOvervoltage Trip

WTG Short TimeOvervoltage Trip

WTG Inst TimeOvervoltage Trip

1.25 p.u.

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Voltage Coordination Plot

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Regulatory Interpretation

• Justify your interpretation to compliance auditor

• Documentation requirements can vary by regulatory district

• Focus on walking compliance auditor through study process to arrive at the same conclusions

Challenges & Lessons Learned

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Data Availability

• Data lost, poor readability, or never delivered

• Atypical data forms

• Data required from manufactures considered proprietary

Challenges & Lessons Learned

Generation Owner/Operator

Generator Manufacturer

Engineer Performing Study

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Additional Questions

• Coordination of volts/hertz protection of the GSU transformer

• GSU Volts/Hertz equipment capability

• Capacitor bank equipment capability

• Tolerance of VAR support system (demonstrate the active voltage band for control)

• Coordination graphs showing VAR/Voltage control scheme, relay settings, and relevant equipment capabilities.

Challenges & Lessons Learned

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Plan Ahead

Keep it Simple

Take it Slow

Combine Studies

Conclusions

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Questions?

An Introduction to Completing a NERC PRC-019-2 Study�For Synchronous and Distributed Generation SourcesPresentation GoalsNERC Reliability Standards���NERC PRC-019-2PRC-019-2 RequirementsExamples of Coordination EvidenceExamples of Equipment Capabilities, �Limiters, and Protection FunctionsSynchronous Generator Study ProcessFacility Data RequiredCompliant P-Q PlotSlide Number 11Slide Number 12Final ReportDistributed or Asynchronous Generation FacilitiesAsynchronous Facility AnalysisIndividual WTG Data�Type I�WTG�TCC��Type III WTG�TCC�Combined Generator AnalysisCombined WTG Data�Collector & GSU�TCC�Plant Level Control AnalysisVAR Control SchemesSlide Number 24Challenges & Lessons LearnedChallenges & Lessons LearnedChallenges & Lessons LearnedConclusionsQuestions?