industry webinar · 2013. 8. 1. · industry webinar per and var updates jordan mallory, standards...

Industry Webinar PER and VAR Updates

Jordan Mallory, Standards Developer Specialist

Soo Jin Kim, Standards Developer

PER and VAR Industry Webinar

July 31, 2013

RELIABILITY | ACCOUNTABILITY 2

• NERC Antitrust Guidelines 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.

• Notice of Open Meeting Participants are reminded that this webinar is public. The access number

was widely distributed. Speakers on the call 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.

Administrative Items


• Development Process and Informal Efforts

• Project 2010-01 – PER-005

• Project 2013-04 – VAR-001 and VAR-002

Agenda

Development Process and

Informal Efforts


Standards Revision Process

• August 2012 NERC Board of Trustees Meeting

FERC commissioners urged the industry to focus on creating a more efficient standards development process

NERC CEO focused on revamping the standards process for more efficiency and efficacy

NERC Board issued a resolution instructing the SPIG, MRC, SC, NERC staff and industry stakeholders to reform its standards program (November 2012)

Old Standards Process (1 to 3 years)

Revised Standards Process (Target: less than 1 year)

SAR – 30 day Comment

Standard Drafting Team

Formed

Informal Comment

Period – 30 days

Formal Comment Period - 30

day s

Formal Comment and Initial Ballot –

45 day comment

period

Multiple Successive Ballot – 30

days

Recirculation Ballot – 10

days

NERC Board Adoption

Filing with Regulatory

Bodies

Informal Development

SAR and Pro forma standard – 45-day

comment period and ballot

SDT Formed

Recirculation Ballot NERC Board Adoption Filing with Regulatory

Bodies

Resolving issues starts early


• Identifies issues and determine possible resolution(s)

• Drafts pro forma standard(s)

Technical drafters Legal

Compliance FERC

• Applies Results-based Standards and P81 concepts

• Build industry consensus through informal outreach

Committees and Sub-committees

Trades, Forums, Professional Organizations

Technical Conferences

• Submit SAR and pro forma documents to Standards Committee



• Informal outreach began February 2013 Ad hoc group formed

o Open to the public for participation

• Numerous meetings, technical conferences, conference calls, and webinars FERC OER staff has been invited to participate in all events

• Integration of Independent Experts’ Report

• Met with NERC Compliance, other internal departments, technical committees and trade groups to receive feedback on the standards Compliance input to RSAW



• Approval received from the Standards Committee to move into formal process 45-day formal comment and ballot period o Comment period: July 19, 2013 – September 3, 2013

o Ballot Pools forming: July 19, 2013 – August 19, 2013

o Ballot and non-binding poll: August 23, 2013 – September 3, 2013

Formal Process


• All projects resolve 67 directives and retire 66 requirements

• MOD A, B and C resolves 49 directives and removes 62 requirements MOD A resolves 20 directives and retires 50 requirements

MOD B resolves 15 directives and retires 5 requirements

MOD C resolves 14 directives and retires 7 requirements

• PER resolves 7 directives and adds 2 requirements

• VAR resolves 11 directives and retires 6 requirements

Project Directives and Requirements

PER Industry Webinar

Jordan Mallory, Standards Developer Specialist

PER Industry Webinar

July 31, 2013


• Possible Solutions in Response to FERC Directives

• PER FERC directives

• Updated System Operator Definition

• Generator Operator Directive

• Support Personnel Directive

• EMS Personnel Directive

• Implementation Plan Directive

• Local Transmission Control Center Directive

PER Agenda


• Comply with the directive New standard

Revised standard

• Alternative method to address concern Equally effective and efficient method

• Explain why the directive is no longer needed May develop Guideline if necessary

Must be supported with technical justification as to why the directive would not be implemented

Possible Solutions Responding to FERC Directives


• Five FERC Directives to the ERO Order 693

o Develop specific Requirements addressing the scope, content and duration appropriate for generator operator personnel.

o Include in PER-002-0, personnel who:

– carry out outage coordination and assessments in accordance with IRO-004-1 and TOP-002-2

– determine SOLs and IROLs or operating nomograms in accordance with IRO-005-1 and TOP-004-0.

o Consider through the Reliability Standards development process, whether personnel that perform functions having an impact on the reliability of the BES, should be included in mandatory training pursuant to PER-002-0.

– Personnel responsible for ensuring that critical reliability applications of the EMS, such as state estimator, contingency analysis and alarm processing packages, are available, up-to-date in terms of system data and produce useable results.

o Direct the ERO to develop modifications to PER-002-0 to include formal training for local control center personnel, that training should be tailored to the needs of the position.

PER Directives


FERC Order 742

o Direct NERC to consider the necessity of developing a similar implementation plan with respect to PER-005-1, Requirement R3.1. (simulation technology)

o Direct NERC to develop a definition of “local transmission control center” in the standards development project for developing the training requirements for local transmission control center operator personnel.

PER Directives Continued


Suggested Definitions

Glossary of Terms Definition: Suggested Change:

System Operator: An individual at a control center (Balancing Authority, Transmission Operator, Generator Operator, Reliability Coordinator) whose responsibility it is to monitor and control that electric system in real time. *Control Center: One or more facilities hosting operating personnel that monitor and control the Bulk Electric System (BES) in real-time to perform the reliability tasks, including their associated data centers, of: 1) a Reliability Coordinator, 2) a Balancing Authority, 3) a Transmission Operator for transmission Facilities at two or more locations, or 4) a Generator Operator for generation Facilities at two or more locations.

System Operator: An individual at a Control Center* that operates or directs the operation of the Bulk Electric System in Real-time.


• Develop specific Requirements addressing the scope, content and duration appropriate for Generator Operator (GOP) personnel No new arguments have been received to date

Current proposed standard complies with the directive

o GOPs are not required to complete training like the RC, BA and TOP

o GOPs are given flexibility in the standard

Generator Operator Directive


• Include in PER-002-0, personnel who: Carry out outage coordination and assessments in accordance with IRO-

004-1 and TOP-002-2

Determine SOLs and IROLs or operating nomograms in accordance with IRO-005-1 and TOP-004-0.

• No new arguments have been received to date

• Current proposed standard complies with the directive Support personnel are not required to complete training like the RC, BA

and TOP

Support personnel are given flexibility in the standard

Support Personnel Directive


• Consider through the Reliability Standards development process, whether personnel that perform functions having an impact on the reliability of the BES, should be included in mandatory training pursuant to PER-002-0. Personnel responsible for ensuring that critical reliability applications of

the EMS, such as state estimator, contingency analysis and alarm processing packages, are available, up-to-date in terms of system data and produce useable results.

• A new argument was provided by the Event Analysis Subcommittee The EAS report will be used as a justification as to why EMS personnel

should not be included in the standard

EMS Personnel Directive


• Direct NERC to consider the necessity of developing a similar implementation plan for entities that may become, in the future, subject to the simulator training requirement in PER-005-1, R3.1 No new arguments have been received to-date


Once the studies show that an entity has an IROL the entity has six months before becoming compliant

o Entity that never had an IROL

Implementation Plan Directive


• Direct NERC to develop a definition of “local transmission control center” in the standards development project for developing the training requirements for local transmission control center operator personnel.

• Direct the ERO to develop through a separate Reliability Standards development project formal training requirements for local transmission control center operator personnel. No new arguments have been received to date


Local Transmission Control Center Directive


• http://www.nerc.com/pa/Stand/Pages/Project2010-01Training.aspx

• Components: Draft Standard PER-005-2

Implementation Plan

Standard Authorization Request

Technical White Paper

Mapping Document

Compliance Input

Proposed Timeline for the Formal Development

Project 2010-01 Project Page

http://www.nerc.com/pa/Stand/Pages/Project2010-01Training.aspx




mailto:[email protected]

VAR Industry Webinar

Soo Jin Kim, Standards Developer

VAR Industry Webinar

July 31, 2013


Ad-Hoc Group Members

Participant Entity Represented

Dennis Chastain TVA

Bill Harm PJM

Steve Hitchens BPA

Sharma Kolluri Entergy

Martin Kaufman ExxonMobil

Joshua Pierce Southern Company

Hari Singh Xcel

Hamid Zakery Calpine

Scott Berry Indiana Municipal Power


Outreach Conducted

• Numerous meetings, conference calls, and webinars

• Two technical conferences were conducted

• Presented the pro formas to the NAGF and NATF

• Presented to ISO/RTO council via conference call

• Met with NERC Compliance and other internal departments to receive feedback on the standards


• Five Major FERC Directives to the ERO from Order No. 693 VAR-001-Summary from P 1880

o Expand the applicability to include reliability coordinators and LSEs;

o Include detailed and definitive requirements on “established limits” and “sufficient reactive resources” and identify acceptable margins above the voltage instability points;

o Include Requirements to perform voltage stability analysis periodically, using online techniques where commercially available and offline techniques where online techniques are not available, to assist real-time operations, for areas susceptible to voltage instability;

o Include controllable load among the reactive resources to satisfy reactive Requirements; and

o Address the power factor range at the interface between LSEs and the transmission grid.

VAR Directives


VAR-002- From PP 1881-1885

o FERC directed NERC to consider modifying VAR-002 to require more detailed and definitive requirements when defining the time frame associated with an “incident” of non compliance (i.e., each 4-second scan, 10-minute integrated value, hourly integrated value)

VAR Directives Continued


• VAR-001 Some advocated for a planning standard, and the consensus was that

was not necessary because we have other standards that address the planning horizon

Did not create hard limits for operating margins, tolerance bands, and stability limits

LSE responsibility for maintaining power factors was very divisive, and the consensus was to remove from VAR pending a final rulemaking for P81

• VAR-002 Some advocated for changing the VAR-002 standard completely, but the

consensus was to keep the focus on addressing FERC directives

There is still a concern about how to best achieve voltage coordination

Major Issues Discussed


Pro Forma Drafted and Posted

• VAR-001 RC added to the standard.

No hard limits or prescriptive margins.

The policies and procedures will dictate frequency of assessments.

Controllable load directive already covered by existing standard.

LSE requirements are proposed to be retired in the P81 NOPR.

Power Factor requirements not added pending the P81 Final Rulemaking.

WECC variance is being retained; therefore, the standard applies to GOPs in WECC.


Pro Forma Drafted and Posted Continued

• VAR-002

Timeframes have been added to VAR-002 to allow GOPs a window for being out of schedule and to correct an issue with an AVR


• Ballot Closes and Comments Due – September 3, 2013

• SDT Nominations Due – August 2, 2013

• Board of Trustees Adoption – November 7, 2013

• File with FERC – December 31, 2013

Upcoming Key Dates


• http://www.nerc.com/pa/Stand/Pages/Project2013-04VoltageReactiveControl.aspx

• Components: Draft Standard VAR-001-4 and VAR-002-3

Implementation Plan

Standard Authorization Request

Technical White Paper

Mapping Document

Compliance Input

Proposed Timeline for the Formal Development

Project 2013-04 Project Page

http://www.nerc.com/pa/Stand/Pages/Project2013-04VoltageReactiveControl.aspx




mailto:[email protected]

industry webinar · 2013. 8. 1. · industry webinar per and var updates jordan mallory, standards...

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