EOP-011-1 Project 2009-03 Emergency Operations Technical Conference - - PowerPoint PPT Presentation

EOP-011-1

Project 2009-03 Emergency Operations

Technical Conference June 24, 2014

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It is NERC’s policy and practice to obey the antitrust laws and to avoid all conduct that unreasonably restrains competition. This policy requires the avoidance of any conduct that violates, or that might appear to violate, the antitrust laws. Among other things, the antitrust laws forbid any agreement between or among competitors regarding prices, availability of service, product design, terms of sale, division of markets, allocation of customers or any other activity that unreasonably restrains competition. NERC Antitrust Compliance Guidelines

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Participants are reminded that this webinar is public. The access number was posted on the NERC website and widely

• distributed. Speakers should keep in mind that the listening

audience may include members of the press and representatives of various governmental authorities, in addition to the expected participation by industry stakeholders. NERC Public Announcement

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• Administrative
• NERC Antitrust Guidelines and Public Announcement
• Background and overview
• FERC Directives
• Attachment 1 of EOP-011-1 and BAL-002 coordination
• Project moving forward
• Discussion and recommendations

Agenda

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EOP Standard Drafting Team

Member Organization David McRee, Chair Duke Energy Bob Staton, Vice Chair Xcel Energy Will Behnke Alliant Energy Richard Cobb Midcontinent ISO, Inc. Jen Fiegel Oncor Electric Delivery Fran Halpin Bonneville Power Administration Hal Haugom Madison Gas and Electric Steve Lesiuta Ontario Power Corporation, Inc. Connie Lowe Dominion Resources Services, Inc. Greg LeGrave Wisconsin Public Service Corp. Brad Young LG&E/KU

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• Present information regarding EOP-011-1
• Question and Answer (Q&A) at the end of each presentation
• Q&A session is intended to improve overall understanding
• Submit questions and comments via the chat feature
• Some question may require additional team consideration
• Webinar and chat comments are not part of the project record
• Discussion and Recommendations
• Submit questions, discussion points and recommendations via the chat

feature

• Some discussion topics may require additional team consideration
• Webinar and chat comments are not part of the project record

Conference Objectives

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• Five-Year Review Overview
• Part of NERC’s broader objective to transition to a clear, concise, and

stable body of world-class, high-quality reliability standards

• Five-year reviews must be conducted on current standards that are due for

assessment and have not been revised in recent standards development projects

• Required by ANSI-accredited Reliability Standards development process

Industry Webinar: Five-Year Review Projects Overview 05/2013 Five-Year Review Projects

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• Five-Year Review Process
• Standard identified as due for five-year review
• Standards Committee (SC) appoints a review team of subject matter

experts (SMEs)

• Recommendation to affirm, revise, or withdraw
• Recommendations posted for 45-day comment period
• SC considers comments
• Reaffirmed recommendation submitted to NERC Board of Trustees (Board) for

approval

• Revised or withdrawn recommendation results in Review Team developing a

Standard Authorization Request (SAR)

Five-Year Review Projects

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• Five-Year Review Objective
• Determine whether the Reliability Standard should be:
• (1) affirmed;
• (2) revised; or
• (3) withdrawn.
• Elements of the Five-Year Review
• FERC directives
• Stakeholder requests for clarity or revision
• Results-Based Standards (RBS) principles
• Paragraph 81 principles

Five-Year Review Projects

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• Five-Year Review Teams
• Appointed by the SC
• Comprehensive five-year review of the standard in accordance with NERC’s

Five-Year Review Template

• Template developed with a small team of SC advisors
• NERC Staff to perform preliminary FERC directives, RBS, and Paragraph 81

evaluations

• Review teams include mix of:
• Previous members of Drafting Team(s) that wrote the standard(s) being

reviewed

• Other industry subject matter experts with relevant experience

Five-Year Review Projects

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• Nov. 11, 2010 – NERC SC authorized moving the Project 2009-03

Emergency Operations SAR forward to standard drafting and appointed a Standard Drafting Team.

• Project 2009-03 involved reviewing and revising
• EOP-001-0
• EOP-002-2
• EOP-003-1
• IRO-001-1
• Project 2009-03 was placed on hold in late 2010/early 2011 due

to project prioritization. Project 2009-03 Background

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• April 22, 2013 – NERC SC appointed eight SMEs to serve on the

Emergency Operations Five-Year Review Team (EOP FYRT) to review and make recommendations regarding:

• EOP-001-2.1b
• EOP-002-3.1
• EOP-003-2
• August 6–September 19, 2013 – The EOP FYRT developed a set
• f recommendations which were posted for a 45-day.

Project 2009-03 Background

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• October 17, 2013:
• NERC SC accepted the recommendations of the EOP FYRT
• Appointed a drafting team
• Authorized posting the SAR developed by the EOP FYRT
• November 6–December 5, 2013: SAR posted for comment

period. Project 2009-03 Background

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• EOP-011-1 was drafted by the Emergency Operations Standard

Drafting Team (EOP SDT) through the examination and consideration of:

• Applicable FERC directives
• EOP FYRT recommendations
• Independent Expert Report
• Paragraph 81 criteria
• SAR
• EOP-011-1 posted for informal comment period so industry

could review and help guide the current body of work. Project 2009-03 EOP - Project Page Project 2009-03 Background

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• An informal comment period for EOP-011-1 was open until

Friday, April 28.

• The EOP SDT held a drafting team meeting May 13–15 to review

comments and further develop the EOP-011-1 standard.

• EOP-011-1 is scheduled to be posted for the first formal

comment period and ballot July 1st.

• Submittal to the Board and subsequent regulatory filing is

targeted for the end of 2014 or early 2015. Key Milestones

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• Project 2009-03 EOP consolidates and replaces EOP-001-2.1b,

EOP-002-3.1, and EOP-003-2 with EOP-011-1.

• Project 2008-02 UVLS consolidates and replaces PRC-010-0, PRC-

020-1, PRC-021-1, and PRC-022-1 with PRC-010-1.

• The respective performance formerly required by EOP-003-2,

Requirements R2, R4, and R7 is reflected in PRC-010-1.

• The EOP and UVLS projects are progressing simultaneously to

properly align legacy standard retirements and revised standard implementations. April 10, 2014 EOP and UVLS Joint Webinar EOP and UVLS Project Coordination

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• Please contact the respective NERC Standards Developers for

more information, to schedule an outreach session, or to be added to a project’s email distribution list:

• Project 2009-03 EOP: Laura Anderson at Laura.Anderson@nerc.net
• Project 2008-02 UVLS: Erika Chanzes at Erika.Chanzes@nerc.net

Additional I nformation

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EOP-011-1 Definition Revision Proposed revised definitions: Energy Emergency - A condition when a Load-Serving Entity or Balancing Authority has exhausted all other resource options and can no longer meet its expected Load obligations. This defined term was revised to provide clarity that an Energy Emergency is not necessarily limited to a Load-Serving Entity.

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EOP-011-1 Definition Revision This defined term, or variations of it, is also used in the instances

• below. The EOP SDT does not believe that the proposed revisions

change the reliability intent of these standard or definitions.

• BAL-002-WECC – Contingency Reserve
• IRO-005-3.1a — Reliability Coordination — Current Day

Operations

• MOD-004-1 — Capacity Benefit Margin
• INT-004-3 – Dynamic Transfers
• Defined term Emergency Request for Interchange

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EOP-011-1 Purpose Statement Purpose: To mitigate the effects of operating Emergencies by ensuring each Transmission Operator and Balancing Authority has developed Emergency Operating Plans, and that those plans are coordinated within a Reliability Coordinator Area.

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EOP-011-1 Functional Entities Functional Entities:

• Balancing Authority
• Reliability Coordinator
• Transmission Operator

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EOP-011-1 Requirement R1

• R1. Each Transmission Operator shall develop, maintain and

implement a Reliability Coordinator-approved Emergency Operating Plan to mitigate operating Emergencies on its Transmission System. At a minimum, the Emergency Operating Plan shall include the following elements: [Violation Risk Factor: High] [Time Horizon: Real-Time Operations, Operations Planning]

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EOP-011-1 Requirement R1

1.1. Roles and responsibilities to activate the Emergency Operating Plan; 1.2. Strategies to prepare for and mitigate Emergencies including, at a minimum:

1.2.1. Notification to the Reliability Coordinator, to include current and projected System conditions, when experiencing an operating Emergency; 1.2.2. Controlling voltage; 1.2.3. Cancelling or recalling Transmission and generation outages; 1.2.4. System reconfiguration; 1.2.5. Requesting the redispatch of generation; 1.2.6. Operator-controlled manual Load shedding plan coordinated to minimize the use of automatic Load shedding; 1.2.7. Mitigation of reliability impacts of extreme weather conditions; and

1.3. Strategies for coordinating Emergency Operating Plans with impacted Transmission Operators and impacted Balancing Authorities.

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EOP-011-1 Requirement R2

• R2. Each Balancing Authority shall develop, maintain and

implement a Reliability Coordinator-approved Emergency Operating Plan to mitigate Capacity and Energy Emergencies. At a minimum, the Emergency Operating Plan shall include the following elements: [Violation Risk Factor: High] [Time Horizon: Real-Time Operations, Operations Planning]

2.1. Roles and responsibilities to activate the Emergency Operating Plan; 2.2. Notification to the Reliability Coordinator, to include current and forecasted conditions, when experiencing a Capacity Emergency or Energy Emergency; 2.3. Criteria to declare an Energy Emergency Alert, per Attachment 1;

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EOP-011-1 Requirement R2

2.4. Strategies to prepare for and mitigate Emergencies including, at a minimum:

2.4.1. Generating resources in its Balancing Authority Area:

2.4.1.1. capability and availability; 2.4.1.2. fuel supply and inventory concerns; 2.4.1.3. fuel switching capabilities; 2.4.1.4. environmental constraints.

2.4.2. Voluntary Load reductions; 2.4.3. Public appeals; 2.4.4. Requests to government agencies to implement their programs to achieve necessary energy reductions; 2.4.5. Reduction of internal utility energy use;

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EOP-011-1 Requirement R2

2.4.6. Customer fuel switching; 2.4.7. Use of Interruptible Load, curtailable Load and demand response; 2.4.8. Operator-controlled manual Load shedding plan coordinated to minimize the use of automatic Load shedding; and 2.4.9. Mitigation of reliability impacts of extreme weather conditions.

2.5. Strategies for coordinating Emergency Operating Plans with impacted Balancing Authorities and impacted Transmission Operators.

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EOP-011-1 Requirement R3

• R3. Each Reliability Coordinator shall approve or disapprove, with

stated reasons for disapproval, Emergency Operating Plans submitted by Transmission Operators and Balancing Authorities within 30 calendar days of submittal. [Violation Risk Factor: Medium] [Time Horizon: Operations Planning ]

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EOP-011-1 Requirement R4

• R4. Each Reliability Coordinator that receives an Emergency

notification from a Transmission Operator or Balancing Authority shall notify, as soon as practical, other impacted Reliability Coordinators, Balancing Authorities and Transmission Operators. [Violation Risk Factor: High] [Time Horizon: Real-Time Operations]

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EOP-011-1 Requirement R5

• R5. Each Reliability Coordinator that has a Balancing Authority

experiencing a potential or actual Energy Emergency within its Reliability Coordinator Area shall initiate an Energy Emergency Alert, as detailed in Attachment 1. [Violation Risk Factor: High] [Time Horizon: Real-Time Operations]

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FERC Directives FERC Directives In the development of the proposed EOP-011-1 reliability standard, the EOP SDT addressed the outstanding FERC directives in Order No. 693 related to Emergency Operations and planning.

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FERC Directives EOP-001-1 Emergency Operations Planning:

• Include reliability coordinators as an applicable entity.
• Consider Southern California Edison’s and Xcel’s suggestions in the

standard development process.

• Clarify that the 30-minute requirement in requirement R2 to state

that Load shedding should be capable of being implemented as soon as possible but no more than 30 minutes.

• Includes definitions of system states (e.g., normal, alert, emergency),

criteria for entering into these states. And the authority that will declare them.

• Consider a pilot program (field test) for the system states proposal.
• Clarifies that the actual emergency plan elements, and not the “for

consideration” elements of Attachment 1, should be the basis for compliance.

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FERC Directives EOP-002-2 Capacity and Energy Emergencies:

• Address emergencies resulting not only from insufficient

generation but also insufficient Transmission capability, particularly as it affects the implement of the capacity and energy Emergency plan.

• Include all technically feasible resource options, including

demand response and generation resources.

• Ensure the TLR procedure is not used to mitigate actual IROL

violations.

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FERC Directives EOP-003-1 Load Shedding Plans:

• Develop specific minimum Load shedding capability that should

be provided and the maximum amount of delay before Load shedding can be implemented based on overarching nationwide criteria that take into account system characteristics.

• Require periodic drills of simulated Load shedding.
• Suggest a review of industry best practices in determining

nationwide criteria.

• Consider comments from APPA and ISO-NE in the standards

development process.

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FERC Directives

• Order No. 693 at P 573 “Demand response covers considerably

more resources than interruptible load. Accordingly, the Commission directs the ERO to modify the Reliability Standard to include all technically feasible resource options in the management of emergencies. These options should include generation resources, demand response resources and other technologies that meet comparable technical performance requirements.”

• Order No. 693 at P 595: “The Commission directs the ERO to

address the minimum load and maximum time concerns of the Commission through the Reliability Standards development process.”

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FERC Directives

• Order No. 693 at P 548: “Further we agree with SoCal Edison

that clear direction is needed on which requirements should be exclusive to transmission operators and balancing authorities with the reliability coordinator being responsible for incorporating this information into its overarching plan. Accordingly, the Commission finds the reliability coordinator is a necessary entity under EOP-001-0 and directs the ERO to modify the Reliability Standard to include the reliability coordinator as an applicable entity. In addition, the ERO should consider SoCal Edison’s suggestion in the ERO’s Reliability Standards development process..”

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Attachment 1 – EOP and BAL-002 Attachment 1

• Operating Reserves removed from EEA 2 and added it to EEA 3

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