Performance Analysis Subcommittee Status Report Highlights and... · 2019-11-26 · Performance Analysis Subcommittee Status Report. Maggie Peacock, PAS Chair. Planning Committee

Performance Analysis Subcommittee Status Report

Maggie Peacock, PAS ChairPlanning Committee MeetingJune 4-5, 2019

RELIABILITY | ACCOUNTABILITY2

• Summary Work Plan updates

Performance Analysis Subcommittee


• PAS: Life after the State of Reliability State of Reliability - After action review Annual metrics review

• GADSWG: GADS Solar data reporting – draft data reporting instructions/1600 data

request pushed to Q1 2020

• TADSWG: Investigation of transmission-connected reactive devices target

completion data updated from TBD to Q4 2020

• MIDASWG: Request for PC reviewers of the functional draft of data reporting

instructions anticipated in Q3

Work Plan Updates


Tim Fryfogle, RAS ChairPlanning Committee MeetingJune 4-5, 2019

Reliability Assessment SubcommitteeStatus Report


Summary• 2019 Summer Reliability Assessment • 2019 Long Term Reliability Assessment• Probabilistic Assessment Working Group• Schedule

Reliability Assessment SubcommitteeOutline


Reliability Assessment Subcommittee2019 Summer Reliability Assessment

2019 Summer Reliability Assessment

Most assessment areas meet or exceed reference margin levels and have sufficient electricity supply resources for anticipated conditions and more extreme scenarios.

• ERCOT anticipates Energy Emergency Alerts may be needed to address resource shortfalls during periods of peak demand. In ERCOT, the anticipated reserve margin remains below the reference margin level of 13.75%. ERCOT’s anticipated reserve margin decreased from 10.9% in summer 2018 to 8.5% for the upcoming summer season.


Reliability Assessment Subcommittee2019 Long-Term Reliability Assessment

Date Milestone

Feb 22 NERC Posts 2019 LTRA Materials to NERC RAS Webpage and sends Request Letter to Regional ExecutivesFeb 23 – June 21 Regional Entities/Assessment Areas Collect Data and Develop Narratives

May 1 – June 21 Individual Assessment Webinars: Upon request, NERC and Individual Assessment Areas / Regions Discuss and Address Data / Narrative Issues

June 21 Regional Entities/Assessment Areas submit Preliminary Data Sheet and Preliminary Narrative to NERC on RASSharepoint

June 26 Peer Review Comment Period Begins: NERC Staff posts Preliminary Narratives and Peer Review Comment Matrix on RAS Sharepoint

July 5 Peer reviewers post completed Peer Review Comment Matrix on RAS SharePoint

July 9-11 RAS Face to Face Meeting: Assessment Area Presentations, Review of Narratives, Discuss Initial Responses to Feedback

July 19 Regional Entities/Assessment Areas post completed Peer Review Comment Matrix on RAS Sharepoint

July 26 Regional Entities/Assessment Areas post the Final Narratives, Area Summaries and Final Datasheet on RAS Sharepoint -Preliminary drafts of the front section and dashboard highlights and writeups to RAS

August 27-28 RAS Face to Face Meeting: Review Front Section Full Dashboards due to RASSeptember 3-6 NERC Staff update front section and Dashboards according to RAS Feedback September 6 NERC Staff provides RAS (by email?) rough draft of report and initial key findings for OC/PCSeptember 10 – 11 PC Webinar: NERC Staff Present Initial LTRA Key Findings to OC/PCSeptember 13 RAS Webinar: Review LTRA Draft (page turn) and RAS to provide Informal Feedback on Key FindingsSeptember 17 NERC to send Draft LTRA Report to PC and RASSeptember 17 – 27 PC Review of Draft LTRA Report September 27 PC provides feedback to NERC by COB on September 27September 30- October 4 NERC Staff Reviews PC FeedbackOctober 7 NERC Staff Sends Updated Report with Comment Matrix to the PCOctober 14 PC Webinar: NERC Staff Hosts Webinar with PC on Updated Report; Discuss Any Remaining FeedbackOctober 14 – 18 PC Electronic Vote for Report AcceptanceOctober 21 – November 8 NERC Technical Publications and NERC Executive Management reviewNovember 11 – 22 NERC Board of Trustees Review of LTRAFirst week of December NERC Board of Trustees Approval of LTRADecember 9 Target Release


• Data collection approaches and recommendations report PC endorse Q4

• Provide a forum for the discussion of probabilistic studies across industry groups and stakeholders Host Q4

• Develop recommendations for LTRA enhancements to incorporate probabilistic analysis Work in progress

• Develop a schedule and scope for the 2020 Probabilistic Assessment

PAWG Work Plan


Reliability Assessment SubcommitteeSchedule

July 9-11 Portland, Or• LTRA Peer ReviewAugust 27-28 Pittsburg, PA• Review front section of LTRA• WRA kickoffNovember 12-14 Miami, FL• Review LTRA data form and instructions for 2020


Subcommittee Leadership Reports and PC Work Plan UpdatesSystem Protection & Control Subcommittee

Mark Gutzmann, System Protection & Control Subcommittee ChairPlanning CommitteeJune 4-5, 2019


Recent Activities

• Last Meeting: May 22, 2019• Current Initiatives (Per PC Work Plan): PRC-019 Draft SAR (Ready for PC Endorsement) PRC-019 Compliance Implementation Guideline PRC-023 Draft SAR


Synchronized Measurement Subcommittee (SMS) Status ReportTim Fritch, Vice-ChairPlanning Committee MeetingJune 4-5, 2019


• White Paper Status • January 11th Oscillation Survey• Next Meetings

Summary


• Recommended Disturbance Monitoring for IBR Conducted several meetings to discuss how to implement changes and

questions from PC reviews Paper to be reformatted into two broad categories:o Potential requirement of synchronized high speed recording at the terminals of

unitso Potential requirement of high speed recording within the units

Plan to request approval in Fall PC meeting

• CIP Implementation Guidance Drafted concise implementation guidance on application CIP-002 for PMUs

and related assets Informally reviewed by NERC CIP assurance team and received commentso More diagramso More focus on assetso Cohesive with past guidelines

Next step is for redline to be voted on by SMS

White Paper


• Eastern Interconnection Oscillation was observed from 08:44:41 UTC (03:44:41 EDT) to 09:02:23 UTC (04:02:23 EDT) on January 11th, 2019

• NERC SMS surveyed industry to better understand the following Awareness of event and mitigations taken Communications between RCs Tools to monitor interconnections for oscillations Improvements on compliance guidelines

• Survey consisted of seven questions and a general comments sections

• Eleven utilities participated in the survey

Oscillation Survey


Oscillation Survey Results

1. Is your company registered as a TOP? RC? Both TOP and RC?

2. Were your operators aware of the 1/11/2019 Eastern Interconnection oscillation during the event(8:44-9:02 UTC)?

2a. If so, how were your operators made aware of the event?

2b. Did your operators take any action for the event on 1-11-2019 ?

3a. Does your company feel there is an industry need to develop PMU data sharing requirement for RCs to help address this concern?

3b. Does your company feel there is an industry need to develop a real-time regional oscillation and source detection tool? (i.e. Fnet)

3c. Should NERC SMS work to identify and address gaps in existing NERC reliability standards on RC to RC coordination? (i.e. IRO-014-3)

0 1 2 3 4 5 6 7 8 9 10

AbstainYesNo

Maybe

AbstainMaybe

YesNo

AbstainYesNo

AbstainYesNo

Plants/GORC:

TOP:Tools:

Yes:No:

TOPRC

Both

Que

stio

ns

# of responses


• Most RCs and TOPs were aware of the event• Few took action during the event to mitigate oscillations (i.e.

removed AGC for units)• Improve PMU data sharing between utilities to provide better

situational awareness and potential source of oscillation• Provide better guidance on operating plans to RC and TOP on

what actions need to be taken• Existing standards needs to be reviewed to see if language

needs to be more descriptive to address these types of events • Investigate tools that provide interconnection oscillation

detection

Observations


• Share results with industry and NERC OC• Discuss with NERC ORS on how we can we proceed to

implement new tools, review existing standards, and increase communication between RC

Next Steps


• October 31, 2019 (Dominion)

Meeting Schedule


NERC SAMS Update

Evan Shuvo, SAMS Vice ChairPlanning Committee MeetingJune 4-5, 2019


• Work Plan Items: Status of deliverables Activities Proposed changes to PC work plan, if any

• Activities for associated working groups: LMTF PPMVTF

• All items presented for PC information• Items in need of PC action in red

Outline


• Node-Breaker Representation in Planning Models Ongoing:o Multi-phase effort underwayo Revising a proposal document previously approved by PC in Dec 2013

– PCEC will be advised of results of review

• Modeling Notification Ongoing:o On the agenda for PC approval of the Modeling Notification Process Document

Complete, seeking PC endorsement for distribution: o Modeling Notification on Pitch controls for Type 1 and Type 2 WTG

– Describes the recommended modeling approaches related to eliminating the wt1p models and replacing them with wt1p_b models, where possible.

SAMS Updates


• MOD-032 Case Creation Survey Ongoing:o Created the survey, updated the scope to reflect changes to work plano NERC staff sent the survey to PC area compliance contacts for a forty five

calendar day response periodo Hosted a webinar, received suggestions and commentso Survey will be live after a few changes are made to clarify some of the questions,

participants have been notified of adjustments

• Develop White Paper and SAR for adding Transmission-Connected Dynamic Reactive Power Resources to “Applicable Facilities” in MOD-025, MOD-026, MOD-027, PRC-019, PRC-024 Ongoing:o Both items were presented to PC for review in March 2019

SAMS Updates


• Reliability Guideline recommending planning studies for comprehensive assessment of BES performance due to changing resource mix(SAMS proposed this work plan to replace the current item: “Conduct interconnection-wide technical studies such as Short-circuit analysis”) Ongoing:o PC Secretary to organize call w/ NERC Staff, SAMS leaders, PCEC

• Clarify “Load Loss” terminology Ongoing:o SAMS created and reviewed White Papero NERC Staff OC and PC coordinators to facilitate ORS review

SAMS Updates

Presenter

Presentation Notes

ORS: Operating Reliability Subcommittee


• Focused on the work items related to phase one activities, remaining work may take them past 2020 Past 2020, the LMTF is more suited to continue its work as a working group

• Ongoing: Load Model (Software) Benchmarkingo All major software vendors benchmarked composite load model successfully;

Additional work on track: beginning implementation and benchmarking of composite load model with DER component and single phase motors.

Robust (Default) Data Setso On-track; LMTF will approve new default data set for Phase 2 (single phase

motor stalling) parameters. Two data sets were posted, 3rd data set with relaxed protection setting is under development

System Impact Assessmento On-track; ongoing information sharing o If the members of the PC organization can support field test, that would be good

for LMTF to know

LMTF Activities


• PPMVTF did not meet in March No further updates besides the requested PC action below

• PPMVTF will meet two times per year (January and July) Next meeting in July

• Application Guide for Modeling Turbine-Governor and Active Power-Frequency Controls in Stability Studies Ongoing:o On the agenda for PC approval

PPMVTF Activities

Presenter

Presentation Notes

PPMVTF did not meet in March, will meet two times per year: January and July.


Inverter-Based Resource Performance Task Force (IRPTF) Update

Jeff Billo, IRPTF Vice ChairOC/PC Joint MeetingJune 4, 2019


Work Plan Notes (1/2)

Work Item Notes Status

IEEE p2800 Monitoring and Support

IEEE p2800 and IRPTF meetings are being held back-to-back in the same location to facilitate collaboration

Reliability Guideline: Recommended Improvements to Interconnection Agreements for Inverter-Based Resources

Finished initial draft at May meeting, seeking OC/PC approval to post for industry comment in June

White Paper: Terminology for Fast Frequency Response and Low Inertia Systems – NERC IRPTF Perspectives

New effort

Ongoing

Ready for Posting

Ongoing


Work Plan Notes (2/2)

Work Item Notes Status

White paper: Coordinated Review of NERC Reliability Standards, and Applicability and Clarity of Standards to Inverter-Based Resources

First cut identified a number of Standards/ Requirements that may need revision. IRPTF will refine and present whitepaper for OC/PC approval in December

Scope Update Scope update will be presented to OC/PC in June

Ongoing

Ready for Approval


• Technical discussion on “Grid Forming” inverter technology• Roundtable discussion on modeling improvements following the

NERC Alert II• Roundtable update on related workshops NERC-hosted relay and inverter manufacturer workshop on fault current

contribution from inverters and impacts on protection ERCOT inverter-based resource workshop NERC, WECC, Western Interconnection transmission entity modeling

workshop

Other Interesting Items from May Meeting


SPIDERWG Updates

Bill Quaintance, Duke Energy Progress, SPIDERWG Vice ChairNERC Planning Committee Meeting June 4-5, 2019


• Four Subgroups with leads Modeling Studies Verification Coordination

• Each subgroup performs its own bi-weekly calls.

SPIDERWG Structure


• Refocused items on Work Plan per PC and PCEC comments, non priority items pushed back.

• Subgroup Highlights Verification o DER Verification Guideline set as high priority.

Studieso UFLS/UVLS Guideline split into two separate Guidelines. Review of TPL-001 and DER

incorporation Guideline prioritized

Coordinationo In conjunction with Modeling group, drafted MOD-032-1 SAR (Later Presentation)

Modelingo DER_A Model Parameterization Guideline ready for PC comment at this meeting (Later

Presentation)

• Internal SPIDERWG survey in development among all subgroups

Work Plan Projects Update


• Next Meeting scheduled for July 24 – 25th for the entire Working Group

• Currently having great involvement in the group and subgroups Great participation with SMEs regarding DER Many if not all subgroups desire a higher Distribution (DPs) presence. Battery technology and modeling pertaining to DER in consideration.

Future Meeting Schedule and Plans


GMD Task Force Update

Ian Grant, TVAPlanning Committee MeetingJune 4-5, 2019


• GMD Research Work Plan is progressing on-track• NERC Standards Committee appointed Standards Drafting Team

(SDT) to addressing Order No. 851 Directives • Next GMDTF meeting set for August 14, 2019 | Chicago

Significant Updates


• Issue: Address concerns to ensure the 1-in-100 year benchmark is not under-estimated

• EPRI will publish the first of two reports from the benchmark GMD event research task this month Final report in Q1 2020 addresses benchmark justification

Upcoming EPRI Report: GMD Data Set

• First report summarizes a database of magnetic data assembled to support GMD research and provides observations: Data set validity is checked by comparing 1-in-100 year localized peak

geoelectric field estimates Data shows strong GMD events can extend to lower latitudes Different (local) times of day may have different GMD risks (geomagnetic

disturbance levels are higher at pre-dawn local time)

• Next Steps: Data set will be further developed to support the ongoing GMD research

Spatial Averaging


• NERC Staff continues internal development of Data Reporting Instruction (DRI)

• GMDTF review and feedback will be solicited in June 2019

• Data will be collected for GMD events that meet or exceed KP-7 Including historical events back to May 2013 On average, 200 KP-7 GMD events occur in

11-year solar cycle

• Applies to Transmission Owners and Generator Owners with GIC and/or magnetometer data

• Anticipate collection to begin in 2020

GMD Data Collection Update

Approved by NERC Board in August 2018


• NERC Board adopted TPL-007-3 in February 2019 Allows for methodology to develop alternative, Canadian-specific GMD

planning event(s); and Addresses Canadian regulatory approval processes for CAPs

• Requirements for U.S. Entities are unchanged from TPL-007-2• TPL-007-3 supersedes TPL-007-2 in U.S. jurisdictions in July 2019

Approved Version of TPL-007


• SDT is appointed to address FERC Order No. 851 Directives for revisions to TPL-007 standard Require entities to implement a CAP to mitigate vulnerabilities from the

supplemental GMD event Implement a process for authorizing case-by-case extensions of CAP

mitigation deadlines

• Revised standard must be filed by July 2020• SDT is considering stakeholder comments from the Standards

Authorization Request (SAR) posting (February – March 2019)

GMD Standards Update (Info)


TPL-007 Implementation

January 1, 2017*

Currently Effective•Responsibilities (R1)•System Models (R2)•GIC Flow Information (R5-Benchmark)

January 2020

•GIC Flow Information (R5/R9)

July 2021•GIC and Magnetic Field Data Process (R11/R12)

January 2022

•Transformer Thermal Assessment (R6/R10)

January 2023

•Voltage Criteria (R3)

•Benchmark GMD VA (R4)

January 2024

•CAP for Benchmark GMD VA (R7)

*January 1, 2017 is when TPL-007 standard became effective (FERC Order No. 830)



NERC GMD Research Plan Objectives

Improved Earth Conductivity

Models

Improved Harmonic Analysis

Capability

00.20.40.60.8

11.21.41.61.8

2

0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 1.8 2 2.2 2.4

pu fl

ux

Current, pu

Per Unit Saturation Curve

Harmonic Impacts

Transformer Thermal Impacts

Spatial Averaging

Latitude Scaling Factor

Geoelectric Field Evaluation• EPRI Project is scheduled to

address all Order No. 830 objectives by Q1 2020

• Support TPL-007 standard• EPRI publishes technical

reports for each objective

Reliability Guideline: DER_A ParameterizationAuthorization to Post for Industry Comment Period



• New DER_A dynamic model now available, and being released, in all major positive sequence simulation software platforms.

• Industry seeking guidance on how to use and parameterize the model

• NERC SPIDERWG developing guidance for how to use the DER_A model, and how to develop parameter values for the model

• This presentation is presenting this guideline to the NERC PC, and requesting to authorize to post for 45-day industry comment period.

Overview


• Provides TP/PCs with more detailed understanding of the model and how to use it

• Provides recommendations for developing parameters values for the model

• Provides guidance pertaining to modeling U-DER and R-DER effectively

• Builds off of the existing NERC DER modeling guidelines developed by NERC LMTF

Overview


• Introduction DER Modeling Framework Background and Overview of DER_A Model

• Annotated DER_A Block Diagram Description of blocks in model

• Parameterization of the DER_A Model Relation to specific interconnection requirements/standards (e.g., IEEE 1547-2003,

IEEE 1547-2018)• Practical DER_A Model Implementation Based on mix of different vintages of IEEE 1547

• DER_A Model Benchmarking an dTesting Ensures the DER_A model is fit for use in industry-wide studies.

• Appendix: References Highlighted references pertaining to each chapter

• Appendix: DER_A Block Diagram

Guideline Outline


DER Modeling Framework

Continuing to build on existing framework; now with DER_A dynamic model that can be used for R-DER or U-DER.


Understanding the DER_A Model


Coming Up with Reasonable Model Parameters

…


• June 4-5, 2019 NERC PC Authorize to Post for Comment

• June 10 – July 25, 2019 Industry Comment Period

• July 29 – Aug. 16 SPIDERWG Response to Comments, Doc Edits

• Sept. 10-11, 2019 NERC PC Final Approval

Proposed Timeline


This presentation is presenting this guideline to the NERC PC, and requesting to authorize to post for 45-day industry comment period.

Proposal


Improvements to Interconnection Requirements for BPS-Connected Inverter-Based Resources Reliability Guideline – Post for Industry Comment

Jeff Billo, IRPTF Vice ChairPlanning CommitteeJune 4-5, 2019


• In 2018, IRPTF developed BPS-Connected Inverter-Based Resource Performance Reliability Guideline Provided performance recommendations Voluntary for GOs

• Industry provided feedback on need for a guideline on how to translate the recommendations into interconnection requirements

Motivation


1. Summary of recommended improvements to interconnection requirements

2. Detailed description of recommended improvements to performance requirements

3. Detailed description of recommended improvements to modeling requirements

Outline


• IRPTF seeks PC and OC approval to post the Improvements to Interconnection Requirements for BPS-Connected Inverter-Based Resources Reliability Guideline for a 45-day industry comment period

The Ask


Modeling Notification ProcessFor PC approval

Evan Shuvo, SAMS Vice Chair Planning Committee Meeting June 4-5, 2019


• What is modeling notification? Informing the industry of modeling development and key findings from

industry modeling efforts.

• Why do modeling notification? To better align the simulated representation of generation, transmission,

and distribution facilities with real world components.

• Where to find them? NERC website

• Who uses them? Those who use the models and simulation tools and perform BPS reliability

studies with the models.

Overview


Process Flowchart


• NERC SAMS reviewed the Modeling Notification Process Document.

• Key updates: Removal of reference to MWG, and focus on SAMS as parent

subcommittee. Clarification of terminology and references to applicable stakeholders. Modifications of sentences to provide more clarification.

• Seeking PC approval today

Updates

Presenter

Presentation Notes

industry continues to struggle with how these models are applied and used in power system stability simulations. Figure shows an illustrative example of system frequency response for an actual disturbance in the Eastern Interconnection compared to the simulation of this same disturbance using a representative seasonal base case. While it is not expected that these responses match exactly, the simulated response should capture the general trends in performance. It is apparent that the modeled and actual response are quite disparate, which is the result of many modeling errors throughout the case.


2019 State of Reliability Report

John Moura, Director of Reliability AssessmentUpdate to Technical CommitteesJune 4-5, 2019

DO NOT CITE OR USE THE DATA IN THIS PRESENTATION – Preliminary Data and Results


• Provide objective, credible, and concise information to policy makers, industry leaders, and the NERC Board of Trustees on issues affecting the reliability and resilience of the North American bulk power system (BPS) Identify system performance trends and emerging reliability risks Determine the relative health of the interconnected system Measure the success of mitigation activities deployed

The State of Reliability: Objective


• Target audience• Layout and graphics• Succinct messaging• Actionable metrics• Relevance to priority risks• From 200+ pages to less than 50!

Vision and Improvements


State of Reliability Report Sections

State of Reliability Major Parts

The North American BPS: By the Numbers

Detailed statistics on peak demand, energy, generation capacity,fuel mix, transmission miles, and functional organizations.

Event Analysis Review A detailed review of qualified events analyzed by NERC, includingroot cause statistics, historical trends, and highlights of publishedlessons learned.

Reliability Indicators A set of reliability metrics that evaluate four core aspects of systemperformance: resource adequacy, transmission performance andavailability, generation performance and availability, and systemprotection and disturbance performance.

Severity Risk Index A composite daily severity index based on generation,transmission, and load loss and compared to prior years.

Trends in Priority Reliability Issues

Data and analysis from various NERC data sources compiled toprovide clear insights on a variety of priority reliability issues(included assessments help provide guidance to policy makers,industry leaders, and the NERC Board of Trustees).


• High Reliability in 2018, No Category 4 or 5 events Hurricane Michael and Florence may still be processed as a Category 3

• Extreme weather events continue to be leading contributor to the largest generation and distribution outages

• Better than expected performance from Texas generation fleet helped meet 2018 summer peak demand; reliability risk in 2019 due to continued capacity deficit

• Continued downward misoperation rate trend• Improving or stable frequency response performance in all

interconnections• Emerging reliability challenges identified as more inverter-based

generation is added

Key Findings and Recommendations


Severity Risk Index (SRI) - Sorted


Severity Risk Index (SRI) –Cumulative


Severity Risk Index (SRI) – Extreme Days (2018)


Severity Risk Index (SRI) – Extreme Days (2014-2018)


Date MilestoneApril 22 OC/PC Webinar: Update on Report

May 9 Report Sent to OC/PC for Comment

Week of May 13 Webinar presentation of draft report to OC/PC

May 20 Comments from OC/PC due to NERC

May 27 Final Report (non-publication version) to OC/PC for acceptance

May 31 Electronic Voting Deadline for Report Acceptance

June 3 NERC Board of Trustees Review

June 11 OC/PC Email Vote Deadline

June 13 NERC Board of Trustees Approval

June 19 Target Release

Draft 2019 SOR Schedule

June 27 FERC Reliability Conference


Inverter-Based Resource Performance Task Force (IRPTF) Scope Update

Jeff Billo, IRPTF Vice ChairPlanning CommitteeJune 4-5, 2019


• The Inverter-Based Resource Performance Task Force (IRPTF) was formed in June 2017 IRPTF reports to both the Operating Committee and the Planning

Committee

• The IRPTF’s original scope needs to be updated to reflect ongoing work

Background


1. Review and document characteristics of BPS-connected inverter-based resources, as identified by events analyses, dynamic simulations, or discussions within the IRPTF

2. Provide guidance to industry related to recommended performance of inverter-based resources, and provide a forum between generator owners, transmission entities, inverter manufacturers, and related industry experts

3. Coordinate data collection and interconnection-wide analyses related to inverter-based resource performance, as necessary

4. Perform system reliability studies to better understand potential BPS reliability impacts from different inverter-based resource performance characteristics and controls capabilities

5. Provide guidance on emerging reliability issues or related topics related to BPS-connected inverter-based resources

6. Coordinate with FERC, IEEE, UL, NFPA, and state jurisdictions to ensure unified solutions to any identified potential reliability issues

7. Coordinate with IEEE P2800 activities to ensure a coordinated response of BPS-connected inverter-based resources. Align terms, practices, and requirements to the extent possible.

IRPTF Activities


1. Reliability guidelines on BPS-connected inverter-based resource performance2. Reliability guidelines on improving interconnection requirements to ensure reliable

integration of BPS-connected inverter-based resources3. White papers, technical reports, or reliability guidelines pertaining to emerging

reliability risks or issues pertaining to BPS-connected inverter-based resources4. Recommended improvements or modifications to NERC Reliability Standards to

ensure clarity and consistency related to inverter-based resources5. Detailed interconnection-wide studies of any potential reliability risks under high

penetration of inverter-based resource (particularly solar PV)6. Webinars and technical workshops to share findings, technical analysis, and lessons

learned to support information sharing across North America7. Other activities as directed by the NERC Planning Committee (PC) and Operating

Committee (OC) in coordination with the Standards Committee

IRPTF Deliverables


• IRPTF seeks PC and OC approval of the updated scope Duration of IRPTF is extended an additional 18 months

The Ask


Electric Gas Working GroupScope ApprovalThomas Coleman, Director,Power Risk Issue and Strategic ManagementPlanning Committee MeetingJune, 2019


• Potential Bulk Power System Impacts Due to Severe Disruptions (November, 2017)

• NERC Workshop (July, 2018)• Planning Committee Strategic Session (January, 2019)• Creation of EGWG to facilitate gathering of experts and drive

resources to educate and inform industry

Background

Presenter

Presentation Notes

(1)Depleted, (2) Salt Caverns, (3) Aquifers More than 15 UGS with than 1000 customer impact


• Author guidelines, white papers, and compliance guidance• Develop educational materials• Provide technical assistance in fuel –related concerns in other

NERC program areas• Provide assistance to NERC Event Analysis evaluations of BPS

disturbances when fuel disruptions are involved

Activities

Presenter

Presentation Notes



• Reliability Guideline Types of analysis Address regional factors that affect fuel assurance Malleable over time

• Recommendations to enhance operational awareness of fuel-related information

• Information that can be used for a range of audiences to describe emerging risks and possible solutions

• Other tasks as deemed appropriate

Deliverables

Presenter

Presentation Notes



• Fuel Supply and delivery chains• Fuel procurement for electric generation• Transmission Planning studies and system analysis• Electric and fuel infrastructure operations

Membership

Presenter

Presentation Notes



• Scope Included in meeting materials

PC Approval of Scope


Modification to PRC-019-2Standards Authorization Request

Jason Espinosa, System Protection & Control Subcommittee MemberPlanning CommitteeJune 4-5, 2019


It is clear to the industry that PRC-019 is a standard developed and written for traditional synchronous generation.

Inverter Based Resources (IBR) are designed and operated in a completely different manner than synchronous generators.

This misalignment forces entities to make interpretations and assumptions of the

requirements.


Revise PRC-019 standard to address the ambiguity and conflicts within the existing standard.

Identify and delineate the differences

between synchronous and asynchronous

generation

Clearly specific requirements that

align with these differences and support system

reliability.

Purpose


• PC Reviewers Sent Comments• Comments Reviewed and Addressed by SPCS

Steps Taken Since March 2019


PC Comments

• It is clear to the industry that PRC-019 is a standard developed for traditional synchronous generation. Where is this clarity by the industry identified?

• Response: Revised the sentence to clarify that the original PRC-019-001 was initially developed for synchronous generation. A standards project existed to modify PRC-019 to incorporate DPRs.


PC Comments

• Have these concerns been documented in a published report or is this white paper the first to do so?

• Response: These have been documented in whitepapers by both the SPCS and SAMS.


PC Comments

• While there may be some ambiguity in certain areas of the standard, there do not appear to be any events that have taken place where compliance with PRC-019 would have prevented the event.

• Response: Additional clarity is needed in specifying the aspects of DPRs that should be coordinated. There are also issues within PRC-019-2 regarding synchronous generation that need to be corrected or clarified to remove ambiguity. We do believe there is a connection between the Blue Cut Fire and Canyon 2 Fire with PRC-019. Some of the inverters may not have coordinated with their equipment capabilities.


PC Comments

• Section 4.2.3.1 should be clarified so that it pertains to IBRs regardless of the type of control that is used (i.e., individual resource controller or plant/facility See the last paragraph of PRC-019 where it clearly states that where

voltage regulating control is done at an aggregate level, applicability is already included under Facilities section 4.2.3

• Response: We agree with you, but coordination also needs to occur beyond the point of interconnection. Especially when you consider that during “Fault Ride Through Mode” the plant controller will relinquish control to the individual inverters.


PC Comments

• Determine whether static or dynamic reactive resources (i.e., capacitor banks, static VAR compensators, STATCOMs etc.) and synchronous condensers should be applicable to all types of generation resources. It appears that these devices would be included in the standard as they are

elements that contribute to voltage control.

• Response: We agree with you. The standard needs to specifically identify whether these devices are included in the standard. Currently, it's unclear whether these devices are included.


PC Comments

• The standard should clearly specify if a synchronous condenser should be treated in the same manner as a traditional synchronous generator for SSSL. It is unclear why this level of specificity is needed as the standard requires

coordination to ensure that device controls operate prior to system protection devices. It should be the utilities responsibility to determine the coordination.

• Response: Since a number of questions from industry on this issue have been raised, it is important that the standard drafting team should provide clarity.


PC Comments

• The standard should clearly specify if stability consideration is necessary for all types of generation resources. The utility should determine the methodology to comply with the

standard.

• Response: The existing theory behind steady state stability is defined through the concept of a synchronous generator. The manual steady state stability limit is irrelevant to the DPRs. There is not a known SSSL methodology for DPRs.


PC Comments

• There are two SARs being considered for PRC-019; one related to the “Transmission-Connected Dynamic Reactive Resources -SAMS White Paper”, and one entitled “NERC PRC-019 SAR”. The later implies that only SVCs connected to generation are applicable to PRC-019. The former implies that all transmission connected SVCs used for ERS are applicable. The two SARs appear to be in conflict.

• Response: We do not disagree with the SAMS SAR. We are silent on this topic at the direction of NERC. The transmission connected reactive devices are better covered in the SAMS SAR.


PC Comments

• PRC-019 updates related to momentary cessation should mimic the changes the PRC-024 SDT are proposing.

• Response: We believe the two standards have different purposes. In order to align with the intent of PRC-019, we believe that if an inverter cannot remove the momentary cessation function then it should coordinate the function set point with the equipment's capability.


PC Comments

Existing Momentary Cessation

Set Point

Momentary Cessation Set Point Range

(Equipment Capability)

DesiredMomentary Cessation

Set Point(Coordinated with

equipment capability)

Momentary Cessation Set Point Range

(Equipment Capability)

DesiredMomentary Cessation

Set Point(Coordinated with

equipment capability)


Next Steps

• PC Endorsement Requested PRC-019 SAR Associated PRC-019 Whitepaper


Draft MOD-032-1 SARRevisions to Address DER in Data Collection for Interconnection-Wide Base Case Creation – Request for PC Reviewers



• MOD-032-1 does not currently include any language that explicitly addresses data collection of aggregate distributed energy resources (DERs)

• SPIDERWG held many technical discussions on the topic, and decided the most effective solution is to develop SAR to include DER as a component in MOD-032-1 Attachment 1 table explicitly

• This presentation provides technical background on SAR developments, and seeks PC review of draft SAR

Overview


• MOD-032-1 does not include any mention of collecting aggregate DER data for purposes of modeling

• Many TPs/PCs rely on MOD-032-1 to gather information from the data/equipment owners, including DP (LSE) loads

• DP (LSE) has some understanding of the aggregate DER connected their network, can provide this information to the TP/PC (just like how it is done for aggregate load information)

• The term “distributed energy resource” is not in the NERC Glossary, and may need to be added to support this SAR. NERC DERTF has proposed definition; SPIDERWG would like to support the

further refinement/development of a term, if needed by SDT

• Previous SAR from DERTF addresses switching LSE to DP in MOD-032-1, this SAR further reiterates the importance of that

Background on Technical Issues


The proposed scope of this project is as follows:• Alignment with SAR submitted by NERC ERSWG LSE should be removed and replaced by DP as applicable

entity in Section 4.1.3 and all instances in standard requirements and attachments.

• Table in Attachment 1 should be updated to include DER in steady-state and dynamics columns. Details of the changes to be considered by the Standard

Drafting Team are included in the “Detailed Description” below.

• Based on above, SDT should consider including definition for “Distributed Energy Resource (DER)” in NERC Glossary of Terms.

Draft SAR Scope


• Attachment 1 Table should reference aggregate DER in the steady-state and dynamics columns. SDT should consider data needed for modeling aggregate DER for purposes

of BPS reliability studies. NERC SPIDERWG proposes SDT consider, at a minimum, the following

information in the table:

Details

Steady State Dynamics Short Circuit

Aggregate Distributed Energy Resources• Aggregate maximum and minimum active power

capacity• Location (correlated to BPS bus location)• Breakdown by type of DER (e.g., by fuel type or

technology)

Aggregate Distributed Energy Resources

No change needed.


• SPIDERWG is in process of developing recommended practices and NERC Reliability Guidelines related to data collection for DER modeling.

• These materials will provide more detailed guidance for TPs and PCs to develop their data requirements and reporting procedures, per MOD-032-1. SDT should use these materials, as they become available, when

determining the specific language for inclusion in the standard requirements revisions.

These more detailed guidelines for data requirements pertaining to DER should not preclude or hold up the revisions to MOD-032-1

Details (cont.)


• June 2019: Presentation to NERC PC

• June–July 2019: NERC PC review period

• August 2019: SPIDERWG review of comments

• September 2019: PC final approval of draft SAR

Proposed Timeline


Seeking PC reviewers to review the draft SAR so SPIDERWG can finalize and prepare final SAR for presentation at next NERC PC meeting

Request


EIPC Overview of Historic and Current Initiatives

John P BuechlerEIPC Executive Director

NERC Planning Committee MeetingOrlando, FL

June 4-5, 2019

Outline

• EIPC Formation, Purpose, Structure and Scope of Activities

• Historic EIPC Studies and Initiatives• Current EIPC Work

– “Roll-Up” Studies• State of the EI Grid Report

– Frequency Response Studies– Designated Entity Transition Process– Other

2

EIPC Formation-2008• In the east, several Planning Authorities started a

dialog to establish an interconnection-wide planning process for the coordinated roll-up and expansion of existing regional and system specific plans

• Those discussions evolved into the EIPC• EIPC as an organization officially formed in 2009

3

EIPC Purpose

• Develop an open and transparent process through an interactive planning dialogue with industry stakeholders

• Foster additional consistency and coordination in the Eastern Interconnection

• Provide an interface with other interconnections• Provide policy makers and regulators with current

and technically sound transmission planning information for the Eastern Interconnection

4

EIPC Scope of Activities • Overview and analytic review of regional transmission plans

using an integrated model of the Eastern Interconnection • Serve as a resource to facilitate analysis of FERC, DOE, NERC,

and even State transmission policy issues, providing a broad interconnection-wide view of the potential impacts resulting from possible regulations

• Focus on interconnection-wide (not regional) analysis– similar to the role that WECC plays in the West

• Work closely with state and federal regulators, EISPC (now NCEP) and other stakeholders on issues of interest to them

5

What is EIPC’s Structure?• EIPC is a voluntary membership organization – members are

NERC registered Planning Authorities (Planning Coordinators) – Currently there are 20 members out of approximately 40

Eastern Interconnection (EI) PAs– Current membership covers over 95% of the EI

• EIPC’s members contribute their resources to the work that is undertaken jointly

• EIPC maintains an interconnection-wide stakeholder process in collaboration with regional stakeholder activities

6

EIPC, EISPC and DOE• EIPC won a 2010 DOE grant, under ARRA funding, to perform

interconnection-wide analysis of various energy policy options• The grant lasted 5 years in three parts: Phase 1, Phase 2, and

the Gas-Electric Interface Study• EISPC (Eastern Interconnection States’ Planning Council) also

won a grant from DOE– Established a working relationship that continues today with the

National Council on Electricity Policy (NCEP) which is the successor group to EISPC

– Provided significant planning information to state regulators and policy makers, and a significant educational opportunity through joint studies

7

Historic EIPC “Roll-Up” Studies• 2010: Roll-up of 2020 Summer regional system expansion

plans as input to DOE grant work• 2010 to 2015: DOE Interconnection Studies Grant

– Three distinct parts – Phase 1, Phase 2, and Gas-Electric Interface– Developed process for stakeholders to access study data that is CEII– Completely transparent process

• 2013: Roll-up of 2018 and 2023 Summer regional system expansion plans

• 2014: Scenario analysis using 2018 and 2023 cases– Heat wave and drought

• 2015: Roll-up of 2023 Summer & Winter regional system expansion plans

8

Other Historic EIPC Initiatives• Provide input to NERC on the revised MOD-032 model

development process• Provide input to DOE-NREL on Eastern Renewable Integration

Study and use of EIPC Roll-up modeling as basis for that study• Numerous presentations to industry groups on study results

and current work activities– Continue to maintain a transparent process through interconnection-

wide and regional stakeholder activities

• Provide input to the DOE Quadrennial Review process• Provide input to DOE on the Annual Transmission Data Report• Provide input to the DOE Order 1000 implementation Reports• Maintain coordination with EI states through EISPC

9

Current EIPC Initiatives• Issuance of the EI “State of the Grid” Report in October 2018• Assume a leadership role in the analysis of the frequency response

of the Eastern Interconnection-per NERC’s request– Report issued in February 2019

• Participating in discussions with NERC & ERAG on potential transition of the “Designated Entity” role to EIPC

• Provide input to DOE Annual Transmission Data Report, congestion studies and other requests

• Implementation of a new, simplified approach to sharing CEII information for FERC Order 1000 and NERC MOD-032 purposes

• Development of an EIPC-reviewed production cost data base• Continue interface with industry groups

– e.g: The new National Council on Electricity Policy (formerly EISPC)• Continue to support FERC and NERC staff

10

EIPC’s “State of the Grid” Report• EIPC issued its first State of the Grid Report for the EI in

October 2018, describing the coordinated planning undertaken to maintain the reliability of the bulk power system

• The Report focuses on EIPC’s historic “Roll-Up” studies that combine the individual regional plans of is members to verify that they work well together

• These EIPC studies may identify potential constraints resulting from interconnection–wide power flow interactions and provide feedback to the Planning Coordinators to enhance their regional plans

• Such studies are also used to analyze various future scenarios of interest to state policymakers and other stakeholders

11

State of the Grid Report (Cont’d)

• The Report concludes that the individual power systems in the EI are being planned in a coordinated manner.

• These EIPC studies demonstrate that the respective Planning Coordinator transmission and interconnection processes have produced transmission plans that are well-coordinated on both a regional and interconnection-wide basis.

• EIPC studies also show that regional transmission plans will require continued interconnection-wide coordination to ensure that individual plans do not conflict with other regional plans.

• EIPC is currently conducting its fourth cycle of “Roll-Up” studies and anticipates completion of that work in the Fall.– This cycle is focusing on 2028 Summer and Winter conditions

12

EIPC Frequency Response Studies

• In July 2017, EIPC created the Frequency Response Task Force (FRTF - now the FRWG) in response to a request from the NERC ERSWG, regarding:

• Change in generation resource mix / reduced inertia due to the addition of non-synchronous generation along with the retirement of traditional generation resources

• Concern with potential exposure to UFLS events• Need for improved frequency responsive simulation models• Establish trending of interconnection frequency response

over time

13

FRTF Objectives for 2018

• To determine Measures 1, 2, and 4 from the ERSWG Measures Framework Report for the Eastern Interconnection (EI)

– Measurement 1 – Synchronous Inertial Response (SIR) of EI

– Measurement 2 – Initial Frequency Deviation Following Largest Contingency

– Measurement 4 – Frequency Response at Interconnection Level

• To provide the results of its analysis to NERC for use in the 2018 LTRA Report

• To develop recommendations for improvement of the models & process used for the analysis

EIPC Report on EI Frequency Response

• As a result of requests for more information regarding the FRTF work, EIPC prepared a Report which was posted in April 2019

• EIPC’s initial efforts have established a framework and baseline for system planners to improve network models going forward to enable them to provide sufficient notice of and time to resolve any impending adverse effect on frequency response.

• EIPC will update its analysis to provide additional information in the years ahead, in support of NERC’s request.

15

2018 Recommendations– The EIPC Report contains four recommendations for modeling as a

result of the 2018 analysis– EIPC/FRWG met with MMWG in March 2019 to discuss these

recommendations– At that meeting there was consensus on the need for a low

inertia case to support frequency response analysis• MMWG will consider such a case as a “Pilot” for the 2020 cycle• MMWG will give consideration to inclusion in the 2021 case list• This case could replace an existing library case

– EIPC will proceed to develop its own model for the 2020 LTRA• Plan to hire a consultant in 3Q-4Q 2019 to build a low inertia case

– EIPC/FRWG will keep MMWG apprised of its work and coordinate with MMWG to improve future library cases w.r.t. frequency response

Designated Entity Transition Process

• In 2014, EIPC expressed an interest in assisting NERC’s implementation of MOD-032 by potentially assuming the role of the “Designated Entity” (DE) to manage the model building process in the East

• Discussions have continued since then, at times including ERAG, MMWG and other stakeholders

• Discussions were paused in the latter part of 2018 to allow orientation of new leadership at NERC and some Regional Entities

• At a meeting on February 5, 2019, the NERC officers and Regional Managers gave a green light to engage in discussions to transfer the DE role from ERAG to EIPC

17

Transition Issues• Develop an Agreement between NERC and EIPC to replace the

current “Interim Designee” Agreement with ERAG• ERAG to review and update the current Interim Agreement as

necessary• EIPC to work with ERAG/MMWG to revise the MMWG Charter and

Procedure Manual as necessary• Target the beginning of the 2020 model building cycle as the

effective date of the transition• During 2019, the existing ERAG/MMWG process will remain in place• EIPC representatives would be allowed to participate during the

transition in order to learn more about the process• EIPC to assume or negotiate a new agreement with Power Tech for

the 2020 model building cycle• Determine how to manage the overlapping period between cycles

18

Reference Material• EIPC State of the Grid Report

– Report https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5bb502d41905f4207c241e4d/1538589397643/EIPC-State+of+the+Eastern+Interconnection+10-3-18.pdf

– Press Release https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5bb503b38165f55177b274f3/1538589619569/Press+Release+EIPC+Completes+State+of+Grid+Report+FINAL+10-4-18.pdf

• EIPC Frequency Response Report– Report

https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5ca541769b747a55f8444c03/1554334072121/EIPC_FRTF_2018_Final_Report_Public_Version_EC_Approved_2019-02-27.pdf

– Press Release https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5ca5433beef1a1d02051d83b/1554334524217/Final+EIPC+Frequency+Response+Analysis+press+release+4-3-19.pdf

19

https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5bb502d41905f4207c241e4d/1538589397643/EIPC-State+of+the+Eastern+Interconnection+10-3-18.pdf

https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5bb503b38165f55177b274f3/1538589619569/Press+Release+EIPC+Completes+State+of+Grid+Report+FINAL+10-4-18.pdf

https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5ca541769b747a55f8444c03/1554334072121/EIPC_FRTF_2018_Final_Report_Public_Version_EC_Approved_2019-02-27.pdf

https://static1.squarespace.com/static/5b1032e545776e01e7058845/t/5ca5433beef1a1d02051d83b/1554334524217/Final+EIPC+Frequency+Response+Analysis+press+release+4-3-19.pdf

Contact Information

• Website: www.eipconline.com

• E-Mail: [email protected]

• John P. Buechler—Executive Director– [email protected]– 631-499-1555

20

http://www.eipconline.com/

mailto:[email protected]

mailto:[email protected]

Questions and Discussion

21

Performance Analysis Subcommittee Status Report Highlights and... · 2019-11-26 · Performance Analysis Subcommittee Status Report. Maggie Peacock, PAS Chair. Planning Committee

Documents