ercot market education transmission 101 · 2017. 5. 31. · • telemetry data which they are...

ERCOT MARKET EDUCATION

Transmission 101

Module 7:Additional Real-Time Topics

Module Topics

• Telemetry for Real-Time Operations• Forced Outage Detection• Voltage Profiles and Support Service• Approval-to-Energize Process• Verbal Dispatch Instructions• Emergency Operating Conditions

Topics:

Module Objectives

• Identify principle uses of Telemetry for Real-Time Operations

• Describe general process of Forced Outage Detection

• Describe the last steps before receiving Approval-to-Energize

• Describe in general the content of a Verbal Dispatch Instruction

• Identify the levels of Emergency Communications and Alerts

Upon completion of this module you will be able to:

Telemetry

• Telemetry Requirements and Standards

• Equipment Operating Ratings and Limits

• Real-Time Data

• Telemetry of Breakers and Switches

• Requests for Telemetry

• Loss of Telemetry

• Telemetry affecting State Estimator

Telemetry Topics

ERCOT Telemetry Requirements

Each QSE and TSP shall continuously provide:• Telemetry data which they are responsible for.• Real-Time status and analog measurements for all

Modeled Transmission Elements.• Notice to ERCOT for known telemetry issues when

data is:• Not available• Unreliable for operational purposes

Telemetry Standard requirements (frequency of updates, means of communication, nomenclature format etc.) are defined in the Protocols, Operating Guides and ICCP Communications Handbook.

ERCOT Telemetry Standards

The Telemetry Standards also define the requirements for:• Performance and observability requirements of voltage

and power flow measurements on modeled Transmission elements.

• Redundancy of telemetry measurement data.• Meeting the State Estimator Standards.• QSE & TSP real-time monitoring and reporting.

Telemetry

Updates are accomplished through a fully redundant communication link called ICCP (ICCP = Inter-Control Center Communications Protocol)

ERCOT real-time operation processes require the update of real-time data from QSEs and TSPs to ensure that processes run with the most up-to-date data.

Real-Time Data

ICCP links are implemented between TSP systems and ERCOT systems. However, TSPsystems communicate with their remote field devices using a variety of differentprotocols. Accurate mapping between TSPs and ERCOT is important!

Telemetry

ICCPERCOT Systems

TSP Control System

Remote Telemetry

TSPManualEntries

Non-Telemetered Data

• All breakers and switches in the Network Model which are used to switch Transmission Elements or Loads

• TSPs manually enter “actual current state” of non-telemetered devices

• Upon loss of telemetry, ERCOT processes use last known state and manually replaced data.

Telemetry of Breakers and Switches

Telemetry

• Telemetry of bus load, voltages, tap position, and flows on Modeled Transmission elements required

• To the extent needed to estimate ALL generation injections and load withdrawals

• Must meet State Estimator performance standard• Implications of inaccurate LMP results vs. the cost to

remedy taken into account• Special requirements for non-load substations

• ERCOT can request additional telemetry to achieve N-1 redundancy

Telemetry of Real-Time Measurements Requirements

Telemetry

ERCOT will discuss the problem with the TSP first before requesting review/calibration of equipment

For telemetered data inconsistent with surrounding data, ERCOT may request the TSP to…• Calibrate/repair the misbehaving equipment

• Request an Outage to calibrate/repair equipment

• Provide ERCOT with plan to re-calibrate/repair in reasonable time

• Provide engineering analysis proving data element is within specifications

Telemetry

* Concern or deficiency cannot be due to any inadequacy of the State Estimator program

• Additional telemetry may be required* if network observability or the measurement redundancy is not adequate to produce acceptable SE results

• ERCOT will provide evidence supporting congestion or reliability problems requiring additional observability

Requests for Telemetry

Telemetry

The TSP is not required to provide telemetry measurements from a location that is not owned by that TSP, if the location owner does not grant access to the TSP for the purpose of obtaining such measurements.

Options available to TSP upon receipt of ERCOT request• Agree with the request and make reasonable effort to

install equipment providing measurements• Provide ERCOT an analysis of the cost to comply with

the request• Appeal the request to the TAC or present an alternative

solution to ERCOT for consideration• If ERCOT rejects the alternative solution, TSP can

appeal request to TAC within 65 days

Requests for Telemetry

Loss of Telemetry

Upon loss of telemetry, each QSE & TSP shall:• Notify ERCOT as soon as practicable when there are

known telemetry issues.• Address the data issues with either a correction of the

telemetry data as soon as practicable, or• Manually replace the data.• Provide an estimated time for resolving if the data will be

out for two or more days.

Telemetry Issues affecting ERCOT Network Security Analysis

When telemetry issues affect Network Security Analysis:• Real-Time telemetry data issues can cause invalid State

Estimator solutions. • ERCOT shall notify the QSE or TSP responsible for the

incorrect telemetry data.• If the QSE or TSP cannot address the issue within 10

minutes, they will verbally agree on the best assumed data to manually replace the data point until the Real-Time issue is resolved.

Telemetry Issues affecting ERCOT Network Security Analysis

• If the QSE or TSP cannot resolve the Real-Time telemetry data issue within two Business Days, it shall provide an estimated time of resolution.

• QSEs and TSPs shall notify ERCOT when the Real-Time telemetry data issue is resolved.

Forced Outage Detection

Forced Outage Detection - Overview

Telemetry

NetworkOperations

ConstraintsReal-Time Dispatch

Security-Constrained Economic Dispatch

Offers

Pricing

Dispatch Instructions

Real-Time Network Security Analysis

Resource Limits

Force Outage Detection

Real-Time Operations

Telemetry

NetworkOperations

Offers

Pricing

Resource Limits

Force Outage Detection SCADA Telemetry

• Provides real-time breaker status and output of Resources

• Provides status of observable Transmission Elements of the Network Operations Model

• ERCOT Operator may consult QSE or TSP regarding discrepancies

Telemetry

NetworkOperations

Offers

Pricing

Resource Limits

Force Outage Detection Forced Outage Detection

Uses logic equations to translate breaker and switch status changes into Transmission Element status changes

Forced Outage Detection (FOD) Purpose• Detect status changes based on associated breaker and

switch status changes for the following Transmission Facilities

Resources Transmission Transformers Loads

• Identify forced outages of Transmission Facilities

• Produce alarms for ERCOT Operators in real-time at same frequency as SCADA telemetry processing

EXAMPLE

Is the Line . . .

Energized?

Line CLine BO

Line A

Is the Load energized?

Resource

Is the Resource on or off?

Does the status match the Current Operating Plan?

OIs the transformer energized?

EXAMPLE

What happens if the Line is . . .

Open on one end?

Line CLine BO C

Line A

Resource

Is the Resource on or off? Does the status match the Current

Operating Plan?

EXAMPLE

What happens if the Line is . . .

Open on both ends?

Line CLine BO

Line A

Resource

Operating Plan?

EXAMPLE

If open on both ends, what happens to the Load?

Line CLine BOO

Line A

Resource

Operating Plan?

Forced Outage Detection uses real-time telemetry to look at the combination of breaker and switch statuses

EXAMPLE

Line CLine BO

Line A

ResourceO

Status Change & Forced

Outage Alarms

Forced Outage Displays

Breaker & Switch Status

Planned Outages

Planned Resource Status

Network Operations Model

Existing Forced Outages

Inputs and Detection

Forced Outage Detection (continued)

Forced Outage

Forced Extension3

Unavoidable Extension

ERCOT Operator is alerted to unplanned outages

Unplanned Outages for QSE and TSP Facilities

ERCOT Operator may request that a QSE or TSP

• Correct the breaker and/or switch status indication causing the alarm

• Enter an Unavoidable Extension, Forced Outage or Forced Extension into the Outage Scheduler

Unplanned Outages for QSE and TSP Facilities

After a configurable time into the Operating Hour, FOD detects a deviation between planned resource status from COP and FOD calculated resource status.

FOD detects a deviation between telemetered Resource status and FOD calculated Resource status

Resource Status Deviations ERCOT Operator is notified of status deviations for QSE Resources

FOD shall notify the ERCOT operator of an unexpected deviation from the operating plan.

Example:

• Planned Resource status from COP is “ON”, and

• Next hour planned status is also “ON”, and

• Resource status calculated by FOD is “OFF”

Resource Status Deviations

ERCOT Operator may verbally request that the responsible QSE correct:

• the breaker and/or switch status indication causing the alarm

• the deviation between COP and the FOD calculated status

Resource Status Deviations

Voltage Profiles and Voltage Support Service

Definitions

Voltage Profile• Normally desired Voltage Set Points for those Generation

Resources in ERCOT, as specified in the Protocols.Voltage Set Point

The voltage that a Generation Resource:• maintains at its Point of Interconnection• is initially communicated via the Voltage Profile• may be modified by a Real-Time instruction from ERCOT or

the interconnecting TSP, (or TSP’s agent) through the Generation Resource or it’s QSE.

Voltage Support Service (VSS) • An Ancillary Service that is required to maintain transmission

and distribution voltages on the ERCOT Transmission Grid within acceptable limits.

System Voltage Profile

Voltage Profile• ERCOT coordinates seasonal studies with TSPs.

• Predetermined distribution of normally desired voltage setpoints across the ERCOT region.

• Based on sound engineering studies.

• Uses the appropriate Network Operations model.

• ERCOT or TSPs may modify voltage setpoints based on current system conditions.

Goal: During Normal Operating conditions, transmission voltages should not exceed 105% nor fall below 95% of the nominal voltage.

Posted VoltageProfile

MIS>Grid>Transmission>Voltage & Dynamic Ratings

Voltage Profiles - ERCOT Responsibilities

Post the Seasonal Voltage Profile on the MIS.

Coordinate with TSPs and QSEs to maintain transmission voltage levels within normal and post-contingency limits.

Coordinate with TSPs to deploy static Reactive Power reserves

Voltage Profiles - TSP Responsibilities

Monitor system voltages and operate static Reactive Resources to maintain Dynamic Reactive Reserves.

Communicate directly with Resource Entities or QSEs to maintain Voltage Setpoints at Generation Resources.

Voltage Profiles – Resource Entity Responsibilities

Maintain transmission system voltages in accordance with the published voltage profiles and as instructed by its QSE or TSP.

Operate with Resource’s AVR in voltage control mode and notify its QSE and TSP of any change in AVR status.

Voltage Set Point instructions shall be completed in no more than five minutes from receipt.

Voltage Profiles – Resource Entity Responsibilities

Except under Force Majeure or if permitted by ERCOT or the interconnecting TSP:

• operate within ± 2% of the posted Voltage Profile at the Point of Interconnection

• provide lagging or leading reactive capability up to the Resources Unit Reactive Limit (URL) at all times

Voltage Profiles - QSE Responsibilities

Ensure that Resources maintain the desired voltage setpoint and respond to VSS instructions. Telemeter Real and Reactive Power, AVR and PSS status to ERCOT.Notify ERCOT of any change in a Resources AVR status.Inform ERCOT if a Resource can not meet its voltage profile.

Definitions

Voltage Profile• Normally desired Voltage Set Points for those Generation

Resources in ERCOT, as specified in the Protocols.Voltage Set Point

The voltage that a Generation Resource:• maintains at its Point of Interconnection• is initially communicated via the Voltage Profile• may be modified by a Real-Time instruction from ERCOT or

the interconnecting TSP, (or TSP’s agent) through the Generation Resource or it’s QSE.

Voltage Support Service (VSS) • An Ancillary Service that is required to maintain transmission

and distribution voltages on the ERCOT Transmission Grid within acceptable limits.

Voltage Support Service

UnitReactive

Limits(URL)

The URL defines the maximumquantity of Reactive Power that

a Generator Resource iscapable of providing (Lagging) or

absorbing (Leading).95

Power Factor

Leading

Lagging

Who provides it • Generating Resources > 20 MVA

• Generation > 20 MVA aggregated to the same bus

• To qualify, must be capable of producing quantity of Reactive Reserve (MVars) at 0.95 power factor at the Resource’s maximum rated real power capability (MWs)

UnitReactive

Limits(URL)

Power Factor

Leading

Lagging

Intermittent Renewable Resources (IRRs)

For Resources operating at:• ≥10% of Nameplate rating – full reactive output required• ≤ 10% of Nameplate rating and unable to support POI

voltage setpoint - ERCOT may require IRR to disconnect.

UnitReactive

Limits(URL)

Power Factor

Leading

Lagging

Generation Resources and TSPs may enter into an agreement in which:• Generation Resource compensates TSP for providing

Voltage Support Service• TSP must certify to ERCOT that the agreement meets the

Resources reactive power requirements

>> Compensation

Not Paid

Resource is not paid for operating within it’s normal operating range

Normal Operating Range(Leading)

Normal Operating Range(Lagging)

>> Compensation

Not Paid MW

VSS VAr’sPaid

When directed by ERCOT, Resource is compensated for operating above it’s normal URL

>> Compensation

Not Paid MW

VSS VAr’sPaid

When directed by ERCOT, Resource is compensated for real power reductions to provide for additional reactive capability

Approval-to-Energize

Last step before new equipment is energized to ensure all aspects of equipment have been accurately and consistently incorporated into all ERCOT Network Models

• Connectivity

• Telemetry Mapping

• Outages

• Characteristics

Approval to Energize Process

What is Approval to Energize?

Required prior to energization of newly installed, removed, or relocated facilities

At least 7 Business Days prior to the planned energization date, ERCOT Operations Support will review the elements planned for energization and issue approvals or rejections

ERCOT requires at least 7 calendar days prior to energization to complete the process and

confirm that equipment is accurately modeled.

Approval

• Is the equipment in the current Network Operations Model?

• Is telemetry being provided to ERCOT with appropriate data quality?

• Is the equipment properly represented in the Outage Scheduler?

If any responses to the questions above are ‘NO,’ then the request is rejected

If the equipment to be energized is not in the current production model:• Market Participant may receive a notice that the equipment

is not in the current model and that approval may be delayed.

• Market Participant is required to call ERCOT Operations and provide details as to when the equipment is expected to be changed in the model.

• With appropriate communications, the energization date should not be delayed.

If the equipment to be energized is not in the current production model:• It impacts the situational awareness of ERCOT Operations.

• Requires a NOMCR to update the model

• Needs to be reflected in the Outage Scheduler

ERCOT will email the Market Participant of approved and rejected energization requests. For rejections, the reason why will be identified.

NOTE: If changes in the field energization date are anticipated, Market Participants must:

• Contact ERCOT Operations with the updated information.

• Update the Outage Scheduler.

On the day of energization:

• Market Participant contacts ERCOT by telephone, requesting permission to energize equipment

Verbal Dispatch Instructions

Verbal instructions are acknowledged by providing the receivingoperator’s identification and by repeating the VDI to ERCOT orally.

Line 1

CLine 2

CLine 3

CLine 4

CLine 5

CLine 6 CB 1

Auto 1 Auto 2

Auto 3

Bus Section Breaker

138A138E

The following section applies only to Verbal Dispatch Instructions (VDIs) issued for Real-Time operations intended to change or preserve the state, status, output, or input of an element or facility of the ERCOT System.

Dispatch Procedures• Most Instructions between ERCOT and TSPs are Verbal.

• TSP shall immediately request clarification of Dispatch Instruction if unable to understand its responsibility under the Dispatch Instruction.

Line 1

CLine 2

CLine 3

CLine 4

CLine 5

CLine 6 CB 1

Auto 1 Auto 2

Auto 3

Bus Section Breaker

138A138E

When issuing a VDI, ERCOT shall: • Confirm the Market Participant’s response if the repeated

VDI is correct;

• Reissue the VDI if the repeated VDI is incorrect; or

• Reissue the VDI or take an alternative action if the VDI was not understood by the Market Participant.

Line 1

CLine 2

CLine 3

CLine 4

CLine 5

CLine 6 CB 1

Auto 1 Auto 2

Auto 3

Bus Section Breaker

138A138E

ID of responsible Entity and instructing authority

Specific TSP facilities subject of Dispatch Instruction

Specific action required

Current operating level or state of facilities subject to instruction

Operating level or state to which facilities will be dispatched

Time of notification of Dispatch Instruction

Time at which TSP is required to initiate dispatch instruction

Time at which TSP is required to complete Dispatch Instruction

Verbal Dispatch Instruction (VDI) reference number

Content of Verbal Dispatch Instructions

Process:1. TSP or QSE notifies ERCOT2. ERCOT shall resolve the conflict

by issuing another Dispatch Instruction

Valid reasons for not complying

If Dispatch Instructions:

• create a safety issue, risk of bodily harm, or possible damage to equipment

• are not in compliance with the Protocols

• conflict with other valid Instructions

Responsibility after Final Dispatch Instructions:TSP is held responsible for complying with Dispatch Instructions in the Nodal Protocols and may be assessed sanctions for not complying

In the Event of Dispute of Dispatch Instructions:ERCOT and TSP will document:• Communications• Agreements• Disagreements• Reasons for their actions

Resolution process follows Alternative DisputeResolution (ADR) Procedure in Protocols

Emergency Operating Conditions

Emergency Operation

Emergency Operation addresses operating conditions……in which reliability of ERCOT system may not be adequate…where a market solution may not be readily apparentERCOT can instruct TSPs and QSES to take actions that would otherwise be discretionary.

Overview

Emergency Condition Communications

Emergency Operations in Real-Time

Energy Emergency Alerts

Communications under Emergency Conditions between ERCOT, QSEs and TSPs may relate to, but are not limited to:

• Weather

• Transmission

• Generation

• Computer Failure

It is essential that good, timely and accurate communication routinely occur between ERCOT, TSPs and QSEs.

Overview

Four Types of Emergency Communications

Operating Condition Notice

Emergency Notice

Advisory

Emergency Notice

Advisory

How ERCOT determines communication type:• Amount of time market has to respond

• May range from days in advance to immediate.

• If time is insufficient, ERCOT may skip one or more of the steps

Emergency Notice

Advisory

Emergency Condition Communications specify:• Severity of the situation

• Area affected

• Areas potentially affected

• Anticipated duration

Emergency Notice

Advisory

For each of the following four levels of communications, ERCOT shall verbally provide notice to all QSEs and TSPs and shall post the information to the MIS Public Area.

TSPs shall notify their DSPs accordingly.

Emergency Notice

Advisory

QSEs and TSPs are expected to:

• Establish and maintain internal procedures for monitoring system conditions

• Implement appropriate measures when conditions warrant

Operating Condition Notices

An Operating Condition Notice is…• First level of communication

• For informational purposes only

• Request for additional information from Market Participants

• Intended to give Market maximum advanced notice of potential issues

Conditions which may warrant anOperating Condition Notice:• Unplanned transmission outages

• Weather-related concerns like:

• Anticipated freezing temperatures

• Hurricanes

• Wet weather

• Ice storms

Operating Condition Notices

Advisory

An Advisory is…Second level of communication.For informational purposes only, butrecognizes that:

• Conditions are developing or have changed

• QSE and/or TSP actions may be prudent in response to impending Emergency Conditions.

• ERCOT may request additional information from QSEs and TSPs.

Advisory

Conditions which may warrant an Advisory Notice:• Anticipated adverse weather.• System conditions are developing or

have changed.• Forced Outages or other operating

conditions not covered by a Constraint Management Plan.

• Availability of resources to serve anticipated demand.

• Projected insecure conditions. • Communication or control system

limitations.

Advisory

When Physical Responsive Capability falls below 3000MW and EEA Level 2 or 3 is anticipated, ERCOT will coordinate with TSPs to utilize:• Outage restoration

• Tap Changer adjustments

• System reconfiguration

• Constraint Management Plans

• 15-Minute Ratings

• Two Hour Rating for Post-Contingency Loading

• Risk of Double-Circuit Contingencies

Advisory

Watch:Third level of communication

• Address Emergency Conditions which exist or are imminent

• ERCOT may require information from QSEs and TSPs

• Grants ERCOT additional operational authority to deal with emergency conditions

Conditions which may warrant a Watch:• Forced Outages, Post-Contingency

overloads or other abnormal operating conditions not covered by a Constraint Management Plan

• Market-based congestion management techniques embedded in SCED are not adequate to resolve transmission security violations

• SCED Failure

If Corrective Action required, ERCOT may:• Send “corrective action” dispatch

instructions to appropriate Market Participants

• Market Participant must comply

If no Market solution is readily apparent, ERCOT may:• Immediately procure Regulation,

Responsive Reserve or Non-Spinning Reserve services from existing offers

• Dispatch instructions to Resources to provide additional Ancillary Services

Emergency Notice

Emergency Notice:Fourth level of communication

• Notification that ERCOT:

• Is in an insecure state

• Cannot maintain minimum reliability standards during the Operating Period

• Immediate action cannot be taken to avoid operating Transmission Elements above their Emergency Limits

• No timely solution is available through SCED or CMPs

Emergency Notice

Emergency Notices are issued for:• Significant disruption to load

(Ex: overloaded Transmission Elements)

• Credible Single Contingencies threatening to cause cascading outages or and/or large-scale service disruption

Emergency Notice

For Transmission Emergency's, ERCOT shall act immediately to return to a reliable state by:• Instructing Resources to change output

• Curtailing or changing DC Tie Load

• Instructing TSPs to drop Load

Overview

Emergency Notice of SCED Failure

What happens if SCED fails?• ERCOT declares a Watch

• Notification posted on MIS Secure Area

When SCED doesn’t solve, ERCOT may instruct Resources to:• hold the previous interval

• move to an Emergency Base Point level

• Reduce Ancillary Service Responsibilities

The purpose of these actions is to provide additional capacity for SCED to dispatch energy.

Overview

Energy Emergency Alert

At times, it may be necessary for ERCOT to reduce System Demand because of a temporary decrease in

available supply.

The Energy Emergency Alert (EEA) provides orderly pre-determined procedures for operating under short supply conditions.

Energy Emergency Alert

• Use market processes to fullest extent practicable

• Provide maximum possible continuity of service

• Maintain the integrity of the ERCOT System

• Reduce the chance of cascading outages

Outlines method of curtailing demand, utilizing

• Load Resources

• Interruptible Load

• Firm Load, when necessary

Energy Emergency Alert (EEA)

> What is an Energy Emergency Alert?

• Use of market processes to the fullest extent practicable without jeopardizing reliability

• A plan to maximize use of ERCOT capability

• Manages Interconnection Reliability Operating Limits (IROLs)

• Leverages Ancillary Services

• Maintains nuclear station service

• Secures startup power

• Operates Resources during loss of communication

• Restoration of services as defined in the Operating Guides

> What is an Energy Emergency Alert?

ERCOT is responsible for:

• Coordinating with QSEs and TSPs.

• Monitoring ERCOT System conditions

• Initiating the EEA levels

• Maintaining transmission security limits

ERCOT may at any time issue an appeal through the public news media for voluntary energy conservation.

EEA Levels

Physical Responsive Capability (PRC) falls below 2,300MW and is not projected to recover within 30 minutes.

Steady State frequency cannot be maintained at a minimum of 59.91 Hz or PRC falls below 1,750 MW and is not projected to recover within 30 minutes

Steady State frequency cannot be maintained at a minimum of 59.8 Hz or PRC falls below 1,000 MW and is not projected to recover within 30 minutes

EEA Levels

Physical Responsive Capability (PRC) falls below 2,300MW and is not projected to recover within 30 minutes.

ERCOT shall take the following steps to maintain steady state system frequency near 60 Hz and maintain PRC above 1,750 MW:

• Issue Dispatch instructions to available and off-line Resources

• Utilize available DC Tie Import Capability

• Instruct QSEs to deploy available ERS capacity

Non-ERCOT

EEA Levels

Steady State frequency cannot be maintained at a minimum of 59.91 Hz or PRC falls below 1,750 MW and is not projected to recover within 30 minutes.

ERCOT shall take the following steps to maintain steady state system frequency at a minimum of 59.91 Hz and maintain PRC above 1,000 MW: • Instruct TSPs to reduce customer load by using voltage

reduction measures or load management plans.• Instruct QSEs to deploy ERS and/or Responsive

Reserve from Load Resources.• Issue a Media Appeal for voluntary energy conservation.• Instruct TSPs to execute available BLTs.• Confidentiality requirements will be lifted, as needed to

restore reliability.

Emergency Response Service (ERS)

Emergency Response Service

QSE QSE QSE

Gen ER

• Deployed by QSEs

• Can be Load, Generation or an aggregate

• Cannot be a registered Generation Resource

• Cannot be an Intermittent Renewable Resource

• Procured by ERCOT for specific contract periods

Block Load Transfers

Non-ERCOT Control Area

Block Load TransfersTransfers Load between ERCOT and Non-ERCOT control areas.

Switches AC connection between control areas

Shall occur only with approval from ERCOT for Planned or Forced Outages, unless a governmental order is issued.

Must be monitored by SCADA

Must be Registered and Metered

Must not jeopardize ERCOT reliability

EEA Levels

Steady State frequency cannot be maintained at a minimum of 59.8 Hz or PRC falls below 1,000 MW and is not projected to recover within 30 minutes• ERCOT shall direct all TSPs to shed firm load in 100 MW

blocks in order to maintain a steady state system frequency at a minimum of 59.8 Hz and to recover 1,000 MW of PRC within 30 minutes.

• TSPs shall not manually drop load connected to Under-Frequency relays.

• TSPs will keep in mind the need to protect the safety and health of the community and the essential human needs of the citizens

If System Frequency drops, ERCOT may skip to Level

If frequency is below 59.8 Hz, ERCOT may immediately begin implementing EEA Level 3.

If frequency is below 59.5 Hz, ERCOT shall immediately begin implementing EEA Level 3

Prorated amounts of Load Shedding are based on the previous year’s peaks.

Guidelines on Shedding Load

3 Maintain System frequency at 59.8 Hz or greater and instruct TSPs to shed firm load in 100 MW blocks.

EEA: Additional Guidelines

ERCOT may skip EEA Steps when…

• Steps aren’t applicable, like when transmission security violations exist

• Insufficient time to implement steps in sequence

However, to the extent practicable, ERCOT shall use Ancillary Services that QSEs have made available in the market to maintain or restore reliability.

EEA Termination

ERCOT shall:• Continue EEA until sufficient Resources are available

• Restore Normal SCED Operations

• Terminate EEA levels in reverse order, where practical

• Notify QSEs and TSPs of level termination

• Maintain a stable system frequency when restoring load

QSEs and TSPs shall:• Implement actions to terminate EEA levels

• Restore loads when specifically authorized by ERCOT

• Report to ERCOT as each level is restored

Module Summary

You should now be able to: • Describe requirements for communication during

Emergency Operations

• Describe impacts of Emergency Conditions on Real-Time Operations

• Explain Energy Emergency Alerts and how they impact Real-Time Operations

ERCOT Website http://www.ERCOT.com

ERCOT Protocolshttp://www.ercot.com/mktrules/nprotocols/

Market Educationhttp://www.ercot.com/services/training/

Market Education ContactTraining@ERCOT.com

Additional Resources

Your Feedback

ERCOT values your feedback on your experience in completing this instructor-led course.

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ercot market education transmission 101 · 2017. 5. 31. · • telemetry data which they are...

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