approved minutes of the june 1 2016 rcc meeting

September 24, 2016

Members, Reliability Coordinating Committee

and

Members, Task Force on Coordination of Operation

Members, Task Force on Coordination of Planning

Members, Task Force on Infrastructure Security and Technology

Members, Task Force on System Protection

Members, Task Force on System Studies

Re: Minutes of the June 1, 2016 RCC Meeting

Sir / Madam:

Attached are the minutes of the June 1, 2016 meeting of the NPCC Reliability Coordinating

Committee; as approved at the September 7, 2016 RCC meeting.

Sincerely,

Phil Fedora Philip A. Fedora

Assistant Vice President-Reliability Services

cc: NPCC Staff

NORTHEAST POWER COORDINATING COUNCIL

Reliability Coordinating Committee Minutes

June 1, 2016

June 1, 2016 2

Mr. Schiavone called the meeting of the Reliability Coordinating Committee (RCC), held at

the New York Times Square Residence Inn by the Marriott to order at 10:00 am.

Attendance

Officers of the Reliability Coordinating Committee

Michael Schiavone, Chair National Grid USA

Brian Evans-Mongeon, Co-Vice Chair Utility Services, Inc.

Randy Crissman, Co-Vice Chair New York Power Authority

Sector 1 - Transmission Owners

Central Hudson Gas & Electric Corp. Frank Pace

Central Maine Power Company David Conroy

Consolidated Edison Company Michael Forte

of New York, Inc.

Hydro-One, Inc. Tom Irvine

Long Island Power Authority Anie Philip – Alternate (via phone)

National Grid USA Michael Schiavone

New Brunswick Power Corporation Randy McDonald (via phone)

New York Power Authority (proxy to Randy Crissman)

New York State Electric & Gas Corp. Ray Kinney (via phone)

Nova Scotia Power Paul Casey

David Stanford (Alternate)

Rochester Gas & Electric Corporation (proxy to David Conroy)

Vermont Electric Power Company, Inc. Hantz Presume

Sector 2 – Reliability Coordinators

New Brunswick Power Corporation (proxy to Randy MacDonald – via phone)

Ontario Independent Electricity System Len Kula

Operator

ISO-New England, Inc. Mike Henderson

New York Independent System Operator (proxy to Zach Smith)

Sector 3 – Transmission Dependent Utilities, Distribution Companies and Load Serving

Entities

Consolidated Edison Company (proxy to Michael Forte)

of New York, Inc.

Eversource Energy Barry Bruun (via phone)

Long Island Power Authority (proxy to Anie Philip – via phone)


Sector 4 Generation Owners

Consolidated Edison Company (proxy to Mike Forte)

of New York, Inc.



June 1, 2016

June 1, 2016 3

Dominion Resources Services, Inc. Connie Lowe (via phone)

Dynegy, Inc. James Watson (via phone)

Eversource Energy (proxy to Barry Bruun)


New York Power Authority Randy Crissman

NextEra Energy Resources (via written proxy)

Ontario Power Generation, Inc. David Ramkalawan (via phone)

Sector 5 – Marketers, Brokers, and Aggregators

Consolidated Edison Company (proxy to Michael Forte)

of New York, Inc.

Long Island Power Authority (proxy to Anie Philip)


Talen Energy Marketing, LLC Elizabeth Davis - Alternate (via phone)

Utility Services, Inc. Brian Evans-Mongeon

Sector 6 – State and Provincial Regulatory and/or Governmental Authorities



New York State Department Ed Schrom

of Public Service

Sector 7 – Sub-Regional Reliability Councils, Customers, other Regional Entities and

Interested Entities

New York State Reliability Council, LLC Roger Clayton (via phone)

NPCC Staff

Sal Buffamante Assistant Vice President Audits and Risk

Assessment

Gerry Dunbar Manager of Reliability Criteria

Requirements

Phil Fedora Assistant Vice President, Reliability Services

Jessica Hala Manager, Finance and Accounting

Damase Hebert Compliance Attorney

Brian Hogue Information Systems & Security

Management

Andreas Klaube Engineer, Operations

Stan Kopman Assistant Vice President Compliance

Enforcement and Mitigation

Quoc Le Manager, System Planning and

Protection

Michael Lombardi Manager, System Studies

Neeraj Lal Senior Reliability Engineer



June 1, 2016

June 1, 2016 4

Scott Nied Manager, Operations and Planning Compliance

Audits

Andrey Oks Director of Operations Coordination

Lee Pedowicz Manager, Reliability Performance and Criteria

Assessment

Paul Roman Director, Operations Planning

Frantz Roc Manager, Information Technologies

Ralph Rufrano Manager, Events Analysis

Rafael Sahiholamal Senior Reliability Engineer

Guy Zito Assistant Vice President of Standards

Guests

Sean Bodkin (via phone) Dominion Resources Services, Inc.

Francois Brassard Hydro-Quebec TransEnergie

Simon Couture-Gagnon (via phone) Chair, SS-38 Load Modeling Working Group

Kevin DePugh Vice Chair, Task Force on System Studies

Farzad Farahmand Ontario Independent Electricity System

Operator

Mark Graham New York Power Authority

John Helme Chair, Task Force on Infrastructure Security

and Technology

Liana Hopkins New York Power Authority

Mohammed Hossain New York Power Authority

Hung Huynh Nova Scotia Power, Inc.

Humayun Kabir New York State Department of Public Service

Dean Latulipe (via phone) Chair, SS-38 Working Group

George Wegh Chair, Task Force on System Protection

Quorum Statement

Mr. Fedora indicated that a quorum had been achieved, by member attendance, proxy or

alternate designation. He also noted having received the following written proxy:

Sector 4 – Generator Owners Alan Schriver - NextEra Energy Resources

Antitrust Guidelines for NPCC Meetings

Mr. Fedora reviewed the NPCC Antitrust Guidelines in the Agenda package, and suggested

contacting NPCC Inc.’s Secretary, Ruta Skucas at (202) 530-6428 for further information.



June 1, 2016

June 1, 2016 5

President & CEO Report Mr. Fedora explained that Mr. Schwerdt was attending the FERC Reliability Technical

Conference; he explained that the following topics would be discussed: 2016 NERC State of Reliability Report; and

Identified Emerging Issues

o International Perspectives

o Resource Mix.

Details regarding the FERC Reliability Technical Conference Panel Sessions have been

provided in the RCC agenda package.

He then introduced Ms. Hala, who provided an overview of the 2017 Draft NPCC Business

Plan &Budget provided in the Agenda package.

She explained that for 2017, NPCC’s total budget and assessments are down by -0.3%. The

Criteria Services division budget decreased by -11.3% primarily related to the termination of

the defined benefit plan. In addition: NPCC is currently fully staffed and there are no additional FTE’s budgeted for 2016;

There has been no change in the Working Capital and Operating Reserve Policy since last

year; and,

The defined benefit pension plan was successfully terminated and fully paid out during 2015.

She showed the breakdown of the percentage of total resources by program area for the

Regional Entity division. Standards and Situation Awareness each represented 10% last year;

in 2017 Standards is down to 7% and Situation Awareness increased to 13% as a result of

reprioritization and reallocation of resources. Standards and IT each have one less FTE, and

Compliance and Situation Awareness are each up one FTE. The IT position moved to

Situational Awareness and Infrastructure Security (SAIS); the Standards position was moved

to Compliance. There were no changes in Criteria Services FTEs.

She noted that the assessment and reprioritization of staffing and resources is ongoing and

will continue through 2017; based on the responsibilities detailed in the business plan,

staffing and funding are assessed to be adequate, barring any unforeseen circumstances or

initiatives.

While the full impact of any special reliability studies to address potential resource adequacy

impacts related to the EPA’s Clean Power Plan are currently unknown, for 2017 NPCC is

budgeting one sub-regional U.S. only reliability study (estimated at $50,000) allocated to

U.S. only Balancing Authorities.

As in previous years, the Compliance Monitoring and Enforcement and Organization

Registration and Certification (CORC) Program costs were allocated to reflect the specific



June 1, 2016

June 1, 2016 6

compliance responsibilities within each of the Canadian provinces within NPCC. Within

Quebec these costs are funded directly by the regulator.

NPCC is fully aligned with ERO Enterprise Strategic Plan and Goals; she highlighted the

following primary 2017 focus areas of focus for the ERO: Reliability Standards are at a relative steady-state; emphasis for 2017 will be on enhanced

periodic reviews of existing standards and assessment of cost-effectiveness;

SAIS: continued focus on cyber and physical security issues;

CORC: Risk-focus initiated in 2015; efficiencies obtained by reducing the use of contract

auditors and enhancing ERO Enterprise-wide consistency; and,

Reliability Assessment and Performance Analysis is addressing both existing and emerging

risks with increased analytical sophistication.

The Working Capital and Operating Reserves Policy remains unchanged since last year: Operating Reserves requirement is a range between 8.33% and 25% (90 days) to provide

more stability in annual funding assessment.

the Working Capital requirement target level of 8.33% (30 days) of the annual budget.

projected RE Total Reserve balance at year end 2017: $3,069,085 (20.26% of total budget)

In response from a question from Mr. Henderson, Mr. Fedora explained that the referenced

sub-regional U.S. only reliability study was a place-keeper for the identification of possible

reliability impacts from the proposed EPA CPP State Implementation Plans and/or other

related State initiatives. These could include (but not limited to) assessment of the NERC

identified Essential Reliability Services of voltage, ramping and frequency performance, for

example.

Chair Report Meeting Agenda

Mr. Schiavone referred the RCC to the Agenda provided in the Agenda package.

The RCC then approved the Agenda.

RCC Scope

Mr. Schiavone reported that the changes received for the RCC included minor editorial

changes and the following clarification to Responsibility No. 12:

12. Revisions to NPCC Regional Guidelines (‘B’ Documents) that have not been incorporated into a

Directory and retirement of those ‘B’ Documents which have had their guideline principles

incorporated into a Reliability Directory.

He said the Scope would be sent to the NPCC Board following the RCC’s recommendation

for their approval of the changes.



June 1, 2016

June 1, 2016 7

Approval of the “Addendum to the 2015 NPCC Overall Transmission Reliability

Assessment: Sensitivity Study on the Impact of Distributed Generation”

Mr. Schiavone reported that by electronic ballot ending 5:00 pm on Thursday, March 31,

2016, the RCC approved the “Addendum to the 2015 NPCC Overall Transmission Reliability

Assessment: Sensitivity Study on the Impact of Distributed Generation.”

The RCC’s quorum (two-thirds of 43) was satisfied by 38 submitted votes; approval was

achieved with 37 votes for, with one abstention.

Consent Agenda The Reliability Coordinating Committee unanimously approved the following Consent

Agenda items (written proxy in favor).

March 2, 2016 Meeting Minutes

The Draft-For-Approval Minutes of the March 2, 2016 Reliability Coordinating Committee

were approved, as provided in the Agenda package, with the corrections noted.

RCC Membership Changes

The following changes to RCC Membership were approved:

Sector 1, Transmission Owners

Mr. Brad Bentley has left Eversource Energy. No replacement has been named.

Mr. Jonathan Appelbaum has left the United Illuminating Company. Ms. Silvia Valerio of

the United Illuminating Company succeeds Mr. Jonathan Appelbaum as the alternate.

Sector 2, Reliability Coordinators

Mr. Franҫois Brassard of Hydro-Québec TransÉnergie succeeds Mr. Pierre Paquet (formerly

of Hydro-Québec TransÉnergie) as the member.

Mr. Stéphane Desbiens succeeds Ms. Caroline Dupuis as the alternate, both of Hydro-Québec

TransÉnergie.

Sector 4, Generator Owners

Mr. Sean Bodkin succeeds Ms. Connie Lowe as the member, both of Dominion Resources

Services, Inc.

Ms. Connie Lowe succeeds Mr. Lou Oberski as the alternate, both of Dominion Resources

Services, Inc.

Sector 6 – State and Provincial Regulatory and/or Governmental Authorities

Mr. Humayun Kabir succeeds Mr. Richard Quimby as the alternate, both of the New York

State Department of Public Service.

Task Force Roster Changes

The following changes to Task Force and Working Group memberships were approved:



June 1, 2016

June 1, 2016 8

Task Force on Coordination of Planning

Mr. Robert Russo of Eversource Energy as the member, succeeding Mr. Brad Bentley, who

has left the company.

Task Force on System Studies

Mr. Vincent Fihey succeeds Mr. Sylvain Bastien as the member, both of Hydro-Québec

TransÉnergie.

Task Force on Infrastructure Security and Technology

Mr. Victor Costanza of the New York Power Authority to serve as the alternate.

IST-2 Telecommunications Working Group

Mr. Troy Wells of the New Brunswick Power Corporation to serve as the member.

SP-7 Working Group on Protection System Misoperation Review

Mr. Anthony Napikoski of the United Illuminating Company to serve as the member.

Mr. Peter Larochelle of NextEra Energy Resources to serve as the member.

SP-9 (Ad Hoc) Working Group on Telecommunication Circuits Used for Teleprotection

and Remedial Action Schemes

Mr. David Lambert from Hydro-Québec TranÉnergie to serve as the Chairman.

Mr. Delavar Khomarlou from Hydro One Networks to serve as the member.

Mr. Nghia (Mike) H. Lac from National Grid USA to serve as the member.

Mr. Martine Lalancette from Hydro-Québec TransÉnergie to serve as the member.

Mr. Daniel M. Markis from National Grid USA to serve as the member.

Mr. Frank Parker from the New York Power Authority to serve as the member.

Mr. Jean-Luc Robichaud from Hydro-Québec TransÉnergie to serve as the member.

Mr. Chuck Victor from Nova Scotia Power Inc. to serve as the member.

SS-38 Working Group on Inter-Area Dynamic Analysis

Mr. Rudi Vega succeeds Mr. Kannan Sreenivasachar as the member, both of ISO-New

England.

Mr. Alexander Rost succeeds Mr. Anish Joshi and Mr. Shounak Abhyankar as alternates,

all of ISO-New England.

RCC Scope

Approved as provided in the Agenda package.

Revised New York A-10 list


NPCC Regional Reliability Plan




June 1, 2016

June 1, 2016 9

Task Force on Coordination of Operation Scope and Terms of Reference


Task Force on Infrastructure Security and Technology Scope


2015 Quebec Area Interim Transmission Review


2015 Ontario Area Intermediate Transmission Review


TransEnergie-Chateauguay BPS Risk Mitigation Extension Request Retirement of NPCC

Guideline B-27 – “Regional Critical Asset Identification”


Reliability Coordinating Committee Actions

NYPA – Alcoa Type 1 Special Protection System (SPS) Removal (SPS #47)

Mr. Graham presented the material included in the Agenda package regarding the New York

Power Authority (NYPA) describing the proposed removal of the St. Lawrence/Alcoa 115

kV SPS (Type I SPS #47).

In 1991 NYPA Operations Planning conducted a study and determined that the SPS was no

longer needed and shortly after the study disabled the scheme. The wiring for the scheme

was left in place in case the scheme would be needed in the future. Since that time the Alcoa

SPS scheme was never required or implemented.

In accordance with the NPCC Regional Reliability Reference Directory No.7, “Special

Protection Systems,” the Task Force on System Studies reviewed the proposed removal of

the St. Lawrence/Alcoa 115 kV SPS and concurred with the removal.

The Task Force on Coordination of Planning reviewed this SPS removal and recommended

RCC approval of the retirement of this Type I SPS.

The RCC then unanimously approved the proposed removal of the St. Lawrence/Alcoa

115 kV SPS Type I SPS #47 (written proxy in favor).

NYPA – Type I Special Protection System (SPS) - Niagara Generator Rejection

Modification (SPS#50)

Mr. Hossain presented the materials included in the Agenda package regarding a proposed

modification to the Niagara Generation Rejection SPS (Type I SPS #50).



June 1, 2016

June 1, 2016 10

The Niagara 230 kV Generation Rejection System Special Protection System (NGRS SPS

#50) was originally installed to protect against a variety of Western New York and Eastern

Ontario contingencies under dynamic and steady-state operating conditions. System

improvements over the past 25 years have alleviated the majority of these conditions and the

NGRS SPS is rarely activated.

Thermal analysis showed no post-contingent thermal overloads for all studied system

configurations. Similarly, stability analysis showed stable system performance for all stuck

breaker faults. NYPA, therefore, recommended the removal of the “Niagara 345 kV breaker

failure” as an initiating incident from the NPCC SPS list.

Considering to the recommendations of the Task Force on System Studies, the Task Force on

System Protection and the Task Force on Coordination of Operation provided in the Agenda

package, the Task Force on Coordination of Planning reviewed this SPS modification for

conformance with NPCC Regional Reliability Reference Directory No. 1 “Design and

Operation of the Bulk Power System”, and recommended RCC for approval of this modified

Type I SPS.

The RCC then unanimously approved the proposed modification to remove 345 kV

breaker failure as an initiating event for the Niagara Generation Rejection SPS #50

(written proxy in favor).

2015 New York Area Comprehensive Area Transmission Review

Mr. DePugh presented the 2015 New York Comprehensive Area Transmission Review report

provided in the agenda package.

The 2015 New York Comprehensive Area Transmission Review (the ‘Review’) provides a

five-year-ahead reliability assessment of the Independent Electricity System Operator

controlled grid and its conformance to the NPCC Design and Operation of the Bulk Power

System (Directory No.1). The forecast and conclusions made in the Review are based on the

integrated results from expected changes in load, transmission and generation up to summer

2020.

The Task Force on System Studies conducted a review and approved the Review.

The Task Force on Coordination of Planning (TFCP) agreed that the Bulk Power System in

New York, as planned through the 2020, will remain in conformance with the NPCC

Directory No. 1 criteria and the NERC Transmission Planning standards TPL-001 to TPL-

004. The Review was conducted in conformance with the TPL standards currently in effect

and the Bulk Electric System definition. The TFCP recommended RCC approval of the 2015

New York Comprehensive Area Transmission.



June 1, 2016

June 1, 2016 11

Mr. Presume asked about the impact of loop flows the New York to New England interface

limits. Mr. DePugh explained that the loop flows modeled were in New England going from

north to south; some of that flow came through New York, and affected the import/export

limits.

Mr. Kula asked if transfers on the western end of the state (from Ontario to New York) are

limited by New York transmission internal restrictions. Mr. DePugh responded that in order

to bring power from the western area to the rest of the state, internal New York constraints

are limiting, unless the western New York generation is correspondingly reduced.

He further explained that generation retirements on the New York 230 kV system, coupled

with load growth and loop flows have made the 230 kV system more constraining than the

345 kV system. Mr. Conroy mentioned that the New York Public Service Commission

(PSC) has identified a public policy need to increase transfer capability west to east; multiple

projects have been proposed that the New York ISO is evaluating. Mr. Smith added that the

New York ISO recently issued their final Viability and Sufficiency Assessment that evaluated

various projects submitted for Western New York through their public policy process (Order

1000); the New York Public Service Commission will be reviewing those projects; a

transmission project will likely be selected next year to address those issues.

The RCC then unanimously approved the 2015 New York Comprehensive Area

Transmission (written proxy in favor).

Nova Scotia Power Inc. - Maritime Link Type I Special Protection System (SPS)

Modification (SPS #119)

Mr. Huynh presented the materials included in the Agenda package regarding Nova Scotia

Power Inc.’s proposed modification to the Type I SPS #119 - "NS 345 kV SPS."

In Nova Scotia, major generation is located in the eastern part of the province while the load

center is located in the central part of the province. The transmission corridor from east to

west consists of 345kV, 230 kV and 138 kV lines. Loss of a 345 kV line in the corridor

requires generation runback in the east utilizing the Type I SPS No. 119, “NS 345 kV SPS.”

The present generation rejection target for SPS# 119 consists of one or two thermal units at

Lingan and Point Aconi. Lingan has four units with net operating of 153 MW each and Point

Aconi has one unit with net operating of 171 MW. By 2017, Nova Scotia will be connected

to the province of Newfoundland via a new VSC HVDC link in a bi-polar configuration.

The Maritime Link will have a 500 MW capability.

This HVDC link provides Nova Scotia with the opportunity to select the HVDC for

generation runback target instead of tripping thermal plants at Lingan or Point Aconi when

the HVDC is in-service. The response characteristics and versatility of HVDC runback are



June 1, 2016

June 1, 2016 12

superior to tripping thermal plants. The HVDC runback by the SPS #119 will be limited to

330 MW net, which is equivalent to the existing generation rejection amount.

Considering to the recommendations of the Task Force on System Studies, the Task Force on

System Protection and the Task Force on Coordination of Operation (provided in the Agenda

package) the Task Force on Coordination of Planning reviewed this SPS modification for

conformance with NPCC Regional Reliability Reference Directory No. 1 “Design and

Operation of the Bulk Power System,” and recommended RCC for approval of this modified

Type I SPS #119.

The RCC then unanimously approved the proposed modification to the Type I SPS#

119 - "NS 345 kV SPS" (written proxy in favor).

SS-37 Working Group – Geo-magnetically Induced Current (GIC) Modeling White

Paper

Mr. Lal explained that the SS-37 Working Group GIC Modeling Data Collection White

Paper provides general information and guidance to aid in the collection of GIC data for

required for facilities that include power transformer(s) with a high side, wye grounded

winding with terminal voltage greater than 200 kV. Siemens PSS®E provides a template to

create a GIC data file; the template is divided into the following sections: Substation (and Bus) Data;

Transformer Data;

Bus Fixed Shunt Data;

Branch Data; and,

Earth Model Data.

The RCC then unanimously approved the GIC Modeling Data Collection White Paper

(written proxy in favor).

Status Reports Mr. Schiavone referred the RCC to the materials provided in the Agenda package; the RCC

discussed the following Agenda items:

NPCC Regional Standards Committee Report

Mr. Zito referred the RCC to the Regional Standards Committee report provided in the

Agenda package, and highlighted the following activities: the current activity to “grade” 24 Standards (and their corresponding Requirements) with

respect to their quality and content;

revision of NPCC Regional Standard PRC-006- NPCC-1, Automatic Underfrequency Load

Shedding against the continent-wide Standard;

revision of an existing regional variance (Quebec) appearing in the NERC PRC-006-2

Automatic Underfrequency Load Shedding Standard;



June 1, 2016

June 1, 2016 13

Filing for the retirement of the NPCC Regional Standard for Disturbance Monitoring (PRC-

002-NPCC-1). FERC approval of the continent wide NERC PRC-002-2 Disturbance

Monitoring and Reporting Requirements Standard and its enforceable date of July 1, 2016

renders the Regional Standard unnecessary; and,

Task Force on Coordination of Operation’s technical comparison between the criteria in

Directory No. 9 and Directory No. 10 against the NERC requirements in MOD-025-2

Verification and Data Reporting of Generator Real and Reactive Power Capability and

Synchronous Condenser Reactive Power Capability.

NPCC Compliance Committee

Mr. Kopman referred the RCC to the Compliance and Enforcement materials provided in the

Agenda package and highlighted the following three items: development of a feedback mechanism to provide recommendations to improve Reliability

Standards based on CMEP implementation and review of events analysis;

outreach seminars designed to present a comprehensive analysis to registered entities related

to the top violated NERC Reliability Standards in NPCC. These seminars provide an in-

depth description of root-cause analysis, factors contributing to violations, lessons learned

and risk assessment training. The first seminar covered CIP-007, PRC-005 and CIP-004;

and,

the Spring NPCC Standards and Compliance Workshop, and plans for the November

Workshop concentrating on Standards that become enforceable in 2016.

Mr. Buffamante then highlighted the following activities provided in the Agenda package: CIP version 5 outreach activities;

on track to complete an Inherent Risk Assessment for every entity registered with NPCC by

the end of the year; and,

the 2016 NPCC Physical Security outreach that analyzing gaps in the Transmission Owner’s

and Transmission Operator’s Physical Security.

Task Force on System Protection SP-7 Working Group Review of Protection Systems Misoperations

Mr. Wegh summarized the activities of the SP-7 Working Group provided in the Agenda

package. as completed through the Fourth Quarter of 2015. He reported that the combined

misoperations caused by Incorrect Setting/Logic/Design Errors and by Relay

Failures/Malfunctions ranges between 40-50% of all the misoperations. By relay technology,

the majority of these are microprocessor-based relays. This is expected as the installed base

of BES relays has grown and changed over time reflecting an increasing population of

microprocessor-based technology.

The SP-7 Working Group also reviewed submittals for Special Protection System (SPS)

operations and misoperations for the Fourth Quarter of 2015 as requested by NERC using the

new SPS reporting Template. There was no reported SPS misoperation during this Quarter.

The SP-7 working Group will be reviewing the First Quarter 2016 Protection System and

SPS Misoperations data and will be reporting the data to NERC by July 15, 2016.



June 1, 2016

June 1, 2016 14

In response to a question from Mr. Mongeon, Mr. Le described NPCC’s involvement in the

development of the NERC Misoperation Information Data Analysis System (MIDAS); Mr.

Sahiholamal described how the MIDAS process will be implemented in NPCC.

SP-9 Working Group on Telecommunication Circuits Used for Teleprotection and

Remedial Action Schemes

Mr. Wegh reported that the SP-9 Working Group is planning its first meeting in June 2016 to

start work on the development of a new NPCC guideline for telecommunication circuits used

for teleprotection and remedial action schemes.

Status of NPCC Directory No. 11 “Disturbance Monitoring Equipment Criteria”

Mr. Wegh stated that the new NPCC Directory No. 11 was developed following the approval

of the NERC standard PRC-002-02 “Disturbance Monitoring and Reporting Requirements”

and the determination by NPCC that PRC-002-NPCC-1 could be retired. The NPCC

Directory No. 11 was developed to address identified differences in Disturbance Monitoring

Equipment coverage requirements between PRC-002-2 and PRC-002-NPCC-1.

He explained that the draft NPCC Directory No. 11 provided in the Agenda package has been

posted in the NPCC Open Process for comments through May 29, 2016. All comments

received will be addressed by Task Force on System Protection at their July meeting. If there

are no significant comments that require another Open Process posting, the draft new NPCC

Directory No. 11 will be submitted for approval at the September 2016 RCC meeting.

Task Force on Infrastructure Security & Technology

Mr. Helme reviewed the Cyber and Physical Security information provided in the Agenda

package.

Task Force on System Studies SS-38 Working Group - Load Modeling Working Group (LMWG)

Mr. Couture-Gagnon summarized the activities of the LMWG provided in the Agenda

package. He noted that representatives on the LMWG were also actively participating on the

NERC Load Modeling Task Force. In addition, LMWG representatives continue to provide

support to Transmission Planners and Planning Coordinators regarding the use of dynamic

load models in NERC Standard TLP-001-4.

SS-38 Working Group

Mr. Le summarized the SS-38 Working Group activities provided in the Agenda package

regarding the assessment of the impact of Distributed Generation under other stressed transfer

scenarios in several areas of the NPCC.

As part of emerging reliability risk and the reliability assessments of distributed generation,

he added that the SS-38 WG will also be conducting additional studies this year to measure

the static & dynamic reactive capability on the transmission system if time permits, and to

determine any potential reliability risks resulting from lower system inertia. This effort is



June 1, 2016

June 1, 2016 15

expected to be completed this fall and a report will be provided at the December RCC

meeting.

Task Force on Coordination of Planning (TFCP) Review of NPCC Document A-10

Mr. Smith summarized the review of NPCC Document A-10 “Classification of Bulk Power

System Elements” currently being undertaken by the TFCP; initial discussions have included:

identification of differences between NPCC BPS and NERC BES applicability;

understanding how the A-10 methodology is applied in each NPCC Area;

reviewing the current list of BPS facilities; and,

reviewing each Area’s interpretation of “significant adverse impact outside of the

local area.”

He explained that members of the newly constituted CP-11 Working Group, with input from

the other Task Forces, plan to develop a detailed scope of this review over its upcoming

meetings. Although not procedurally required, the TFCP plans to bring the CP-11 Working

Group Scope of Work to the RCC for approval before starting work.

2016-2017 Work Plan Progress

Mr. Schiavone referred the RCC to the materials provided in the Agenda package.

NPCC Reliability Assessment Program (NRAP) Highlights Report

Mr. Fedora reported at the NRAP Highlights Report was updated as of May 27, 2016 and has

been posted on the NPCC website.

NERC Agenda Items Operating Committee

Mr. Rufrano reviewed the following Draft June 2016 NERC Operating Committee Agenda

items for approval: the revised PJM RTO Reliability Plan;

archiving the NERC Backup Control Center – A Reference Document;

the Dynamic Transfer Reference Document (Version 3); and,

the Time Monitoring Reference Document (Version 4).

He also mentioned that the Functional Model Advisory Group is in the process of revising

the NERC Functional Model, “to ensure the model correctly reflects the industry today and

evaluates and incorporates new and emergent reliability related tasks.”

Planning Committee

Mr. Fedora reviewed the following approval items on the Draft March Planning Committee

Agenda: the 2016 Summer Reliability Assessment;

the Reliability Guideline for Initial Review: Reactive Power Planning and Operations;



June 1, 2016

June 1, 2016 16

the Reliability Guideline for Initial Review: Power Plant Model Verification using PMUs;

and,

Phase Angle Monitoring Technical Report.

He also highlighted the following informational items: topics for the next NERC Short-Term Special Assessment;

the Reliability Assessment Subcommittee 2016 Long Term Reliability Assessment schedule,

the Probabilistic Assessment Improvement Task Force recommendations;

status update for the Essential Reliability Services Working Group & Distributed Energy

Resources Task Force activities; and,

revisions to the NERC Functional Model.

Critical Infrastructure Protection Committee

Mr. Hogue highlighted the following items on the Draft June 2016 NERC Critical

Infrastructure Committee Agenda; RedTeam Security video (link in the E-ISAC presentation);

Remote Access Study update;

Functional Model Advisory Group update; and,

EMP-Rated Control Room Rebuild.

Informational Items Mr. Schiavone referred the RCC to the materials included in the Agenda package. The

following Informational Items were discussed at the meeting:

Event Analysis Program Status

Mr. Rufrano provided an overview status of the Event Analysis Program provided in the

Agenda package.

NERC/FERC Data Requests

Mr. Fedora noted that the NERC Synchronized Measurements Subcommittee (SMS)

requested Reliability Coordinators provide synchrophasor data from Phasor Measurement

Units (PMUs) or other Dynamic Disturbance Recorders to assess the oscillation behavior of

the Eastern Interconnection for selected events. This is a test Section 800 data request for

PMU data to be used for a Special Reliability Assessment on Oscillation Analysis to be

performed by NERC staff and the NERC SMS. Data was requested to be submitted

electronically by May 10, 2016. NERC indicated it would treat this data as Confidential

Information pursuant with its Rules of Procedure, Section 1500.

Eastern Interconnection Reliability Assessment Group Activities

Mr. Roman reviewed the Eastern Interconnection Reliability Assessment Group Activities

provided in the Agenda package. He noted that the six Eastern Interconnection Regions now

have a signed Agreement with NERC to be the Designee under Requirement 4 of MOD-032-



June 1, 2016

June 1, 2016 17

1 through ERAG, and will follow the NERC requirements for the Designee to compile and

produce the annual sets of Eastern Interconnection power flow and dynamic simulation base

cases. Mr. Lombardi added that the agreement was discussed at the Task Force and System

Studies and the SS-37 Working Group; ISO-New England agreed to be the Data Coordinator

for the NPCC Planning Coordinators.

Other Matters Mr. Clayton asked if the new Type III NYPA - Marcy-South Series Compensation SPS was

temporary. Mr. DePugh said the SPS would be considered temporary until a more

permanent solution is found. Mr. Smith added that the NYPA proposed the SPS to eliminate

the possibility of Sub Synchronous Resonance at the Fitzpatrick plant; that plant has recently

announced its intent to deactivitate. If the plant deactiviates, there would be no need for this

SPS; the SPS would be retired at that point.

With no other matters to consider, the RCC meeting was adjourned.

Next RCC Meeting Date Location

Wednesday, September 7, 2016

Toronto Marriott Downtown Eaton Centre

Hotel

Distribution of Approved Minutes

NPCC Full & General Member Representatives and Alternates

Members, NPCC Board of Directors

Members, NPCC Reliability Coordinating Committee

Members, NPCC Public Information Committee

Members, NPCC Compliance Committee

Members, NPCC Regional Standards Committee

Members, NPCC Task Force on Coordination of Operation

Members, NPCC Task Force on Coordination of Planning

Members, NPCC Task Force on Infrastructure Security and Technology

Members, NPCC Task Force on System Protection

Members, NPCC Task Force on System Studies

NPCC Officers

NPCC Staff

Ruta Skucas, Esq.

and

Federal Energy Regulatory Commission – Mike Bardee, David O’Connor, Juan Villar

La Régie de L’Énergie – Daniel Soulier

Ontario Energy Board – Peter Fraser

United States Department of Energy – David Meyer

New Brunswick Department of Energy and Mines – David Sallows

Nova Scotia Utility & Review Board – S. Bruce Outhouse, Q.C.