VAR Outreach Presentation...transmission grid; Table until FERC issues a final rulemaking on P81. VAR Directives. 6 RELIABILITY | ACCOUNTABILITY VAR-002- From PP 1881-1885 o FERC directed

VAR Outreach Presentation

Soo Jin Kim, NERC Standards Developer

November 4, 2013

RELIABILITY | ACCOUNTABILITY2

• 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 informational break-out session is

public. Please keep in mind that the audience may include members of the press and representatives of various governmental entities, in addition to the industry stakeholders.

Administrative Items


• Introductions

• Evolving Standards Process/Informal Development

• FERC directives

• Major changes to the VAR-001 and VAR-002 standards

• Upcoming and key dates

Agenda


Evolving Standards Process

• May 2012: NERC Board adopted SPIG report with recommendations to improve both the timeliness and quality of the standards was adopted.

• August and November 2012 NERC Board of Trustees Meeting:

FERC commissioners urged the industry to focus on creating a more efficient standards development process (August 2012)

NERC CEO expressed there should be a focus on revamping the standards process for more efficiency and quality (August 2012)

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

Informal Development

SAR and Pro forma standard – 30-day comment period

SDT FormedFormal Comment &

Initial Ballot Period – 45 days

Recirculation Ballot

NERC Board Adoption

Filing with Regulatory

Bodies

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

Old Standards Process – Took multiple years

Evolving Standards Process – one year


• 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; Tabled until FERC rules on IRO filing

o Include detailed and definitive requirements on “established limits” and “sufficient reactive resources” and identify acceptable margins above the voltage instability points; Addressed in an equally effective and efficient manner

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; Addressed in an equally effective and efficient manner

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

o Address the power factor range at the interface between LSEs and the transmission grid; Table until FERC issues a final rulemaking on P81.

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); Addressed in VAR-001.

VAR Directives (Cont’d)


• Reliability Coordinators are NOT included for now. This directive must wait until FERC acts on the IRO filing.

• We removed “policies or procedures” that establish, monitor, and control voltage levels and Reactive Power flows.

• There is a reference to the FAC standards by stating the schedules are part of a plan to operate within SOLs and IROLs.

• Exemptions can apply to schedules, AVR status, and notifications.

• TOPs now will provide GOP notifications for deviations from schedules

• TOPs must provide the criteria used to set schedules for GOPs within 30 days of a request.

• TOPs must discuss implementation schedule for GOP tap changes.

Major VAR-001 Changes Since Last Posting


• New R1- Each Transmission Operator shall specify a system voltage schedule

(which is either a range or a target value with an associated tolerance band) as part of its plan to operate within System Operating Limits and Interconnection Reliability Operating Limits. [Violation Risk Factor: High] [Time Horizon: Operational Planning]

1.1. Each Transmission Operator shall provide a copy of the voltage schedules and associated tolerance bands to its Reliability Coordinator and adjacent Transmission Operators within 30 calendar days of a request.



• New R2- Each Transmission Operator shall schedule sufficient reactive resources

to regulate voltage levels under normal and Contingency conditions. Transmission Operators can provide sufficient reactive resources through various means including, but not limited to, reactive generation scheduling, transmission line and reactive resource switching, and using controllable load. [Violation Risk Factor: High] [Time Horizon: Real-time Operations, Same-day Operations, and Operational Planning]



• New R3- Each Transmission Operator shall operate or direct the Real-time

operation of devices to regulate transmission voltage and reactive flow as necessary. [Violation Risk Factor: High] [Time Horizon: Real-time Operations, Same-day Operations, and Operational Planning]



• New R4- The Transmission Operator shall specify the criteria that will exempt

generators from compliance with the requirements defined in Requirement R5, part 5.1, and any associated notification requirements. [Violation Risk Factor: Lower] [Time Horizon: Operations Planning]

4.1. If a Transmission Operator determines that a generator has satisfied the exemption criteria, it shall notify the associated Generator Operator.



• New R5- Each Transmission Operator shall specify a voltage or Reactive Power

schedule (which is either a range or a target value with an associated tolerance band) at either the high voltage side or low voltage side of the Generator Step-Up transformer at the Transmission Operator’s discretion. [Violation Risk Factor: Medium] [Time Horizon: Operations Planning]

o 5.1. The Transmission Operator shall provide the voltage or Reactive Power schedule to the associated Generator Operator and direct the Generator Operator to comply with the schedule in automatic voltage control mode (the AVR is in service and controlling voltage).

o 5.2. The Transmission Operator shall provide the Generator Operator with the notification requirements for deviations from the voltage or Reactive Power schedule.

o 5.3. The Transmission Operator shall provide the criteria used to develop voltage schedules and associated tolerance bands to the Generator Operator within 30 days of receiving a request.



• New R6- After consultation with the Generator Owner regarding necessary step-

up transformer tap changes and the implementation schedule, the Transmission Operator shall provide documentation to the Generator Owner specifying the required tap changes, a timeframe for making the changes, and technical justification for these changes. [Violation Risk Factor: Lower] [Time Horizon: Operations Planning]



• Exemptions and testing are now written into the requirements for AVR settings.

• GOPs must meet the notification requirements of the TOPs.

• The standard now explicitly states it is appropriate for GOPs that do not monitor on the high side of a GSU to use a conversion methodology to determine how to set their AVRs.

• GOPs still have 15 minutes to restore a status change before reporting an AVR status change.

• A new requirement has been added requiring GOPs to report reactive capability changes within 30 minutes of becoming aware of the change.



• New R1- The Generator Operator shall operate each generator connected to the

interconnected transmission system in the automatic voltage control mode (with its automatic voltage regulator (AVR) in service and controlling voltage) unless the Generator Operator 1) is exempted by the Transmission Operator, or 2) has notified the Transmission Operator of one of the following: [Violation Risk Factor: Medium] [Time Horizon: Real-time Operations]

o That the generator is being operated in start-up,1 shutdown, or testing mode pursuant to a Real-time communication or a procedure that was previously provided to the Transmission Operator; or

o That the generator is not being operated in the automatic voltage control mode for a reason other than start-up, shutdown, or testing.



• New R2- Unless exempted by the Transmission Operator, each Generator Operator shall

maintain the generator voltage or Reactive Power schedule3 (within each generating Facility’s capabilities4) provided by the Transmission Operator, or otherwise shall meet the conditions of notification for deviations from the voltage schedule provided by the Transmission Operator. [Violation Risk Factor: Medium] [Time Horizon: Real-time Operations]

2.1. When a generator’s AVR is out of service or the generator does not have an AVR, the Generator Operator shall use an alternative method to control the generator reactive output to meet the voltage or Reactive Power schedule directed by the Transmission Operator.

2.2. When directed to modify voltage, the Generator Operator shall comply or provide an explanation of why the schedule cannot be met.

2.3. Generator Operators that do not monitor the voltage at the location specified in their voltage schedule shall have a methodology for converting the scheduled voltage specified by the Transmission Operator to the voltage point being monitored by the Generator Operator.



• New R3- Each Generator Operator shall notify its associated Transmission

Operator of a status change on the AVR, power system stabilizer, or alternative voltage controlling device within 30 minutes of the change. If the status has been restored within the first 15 minutes of such change, then there is no need to notify the Transmission Operator. [Violation Risk Factor: Medium] [Time Horizon: Real-time Operations]



• New R4- Each Generator Operator shall notify its associated Transmission

Operator within 30 minutes after becoming aware of a change in reactive capability due to factors other than a status change described in Requirement R3. If the capability has been restored within the first 15 minutes of such change, then there is no need to notify the Transmission Operator. [Violation Risk Factor: Medium] [Time Horizon: Real-time Operations]



Directives Team

• Jordan Mallory- PER (Training): PER-002 and PER-005

• Steven Noess- MOD B (modeling data): MOD-010 through MOD-015

• Darrel Richardson- MOD C (demand data): MOD-016 through MOD-021

• Ryan Stewart- MOD A (ATC, TTC, CBM): MOD-001, MOD-004, MOD-008, MOD-028, MOD-029 and MOD-030

Other Directives Projects


• November 4, 2013- VAR webinar; please register on the NERC calendar

• November 25, 2013- Successive Ballot Closes

• December 2-4, 2013- VAR team meeting in Portland

• The VAR SDT hopes to post for a final ballot before the end of the year.

Upcoming Key Dates


Contact Information:[email protected]
mailto:[email protected]

Documents

VAR Outreach Presentation...transmission grid; Table until FERC issues a final rulemaking on P81. VAR Directives. 6 RELIABILITY | ACCOUNTABILITY VAR-002- From PP 1881-1885 o FERC directed