Reliability Standard VAR-001-4.2

VAR-001-4.2 — Voltage and Reactive Control

A. Introduction
1.

Title:

2.

Number: VAR-001-4.2

3.

Purpose: To ensure that voltage levels, reactive flows, and reactive resources are monitored,
controlled, and maintained within limits in Real-time to protect equipment and the reliable
operation of the Interconnection.

4.

Applicability:

Voltage and Reactive Control

4.1. Transmission Operators
4.2. Generator Operators within the Western Interconnection (for the WECC Variance)
5.

Effective Date:
5.1. The standard shall become effective on the first day of the first calendar quarter after the
date that the standard is approved by an applicable governmental authority or as otherwise
provided for in a jurisdiction where approval by an applicable governmental authority is
required for a standard to go into effect. Where approval by an applicable governmental
authority is not required, the standard shall become effective on the first day of the first
calendar quarter after the date the standard is adopted by the NERC Board of Trustees or as
otherwise provided for in that jurisdiction.

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VAR-001-4.2 — Voltage and Reactive Control

B. Requirements and Measures
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: Operations Planning]
1.1. Each Transmission Operator shall provide a copy of the voltage schedules (which is either a
range or a target value with an associated tolerance band) to its Reliability Coordinator and
adjacent Transmission Operators within 30 calendar days of a request.
M1. The Transmission Operator shall have evidence that it specified system voltage schedules using
either a range or a target value with an associated tolerance band.
For part 1.1, the Transmission Operator shall have evidence that the voltage schedules (which is
either a range or a target value with an associated tolerance band) were provided to its Reliability
Coordinator and adjacent Transmission Operators within 30 calendar days of a request. Evidence
may include, but is not limited to, emails, website postings, and meeting minutes.
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 Operations Planning]
M2. Each Transmission Operator shall have evidence of scheduling sufficient reactive resources based
on their assessments of the system. For the operations planning time horizon, Transmission
Operators shall have evidence of assessments used as the basis for how resources were scheduled.
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 Operations Planning]
M3. Each Transmission Operator shall have evidence that actions were taken to operate capacitive and
inductive resources as necessary in Real-time. This may include, but is not limited to, instructions to
Generator Operators to: 1) provide additional voltage support; 2) bring resources on-line; or 3)
make manual adjustments.
R4. Each Transmission Operator shall specify the criteria that will exempt generators: 1) from following
a voltage or Reactive Power schedule, 2) from having its automatic voltage regulator (AVR) in
service or from being in voltage control mode, or 3) from having to make any associated
notifications. [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.
M4. Each Transmission Operator shall have evidence of the documented criteria for generator
exemptions.
For part 4.1, the Transmission Operator shall also have evidence to show that, for each generator in
its area that is exempt: 1) from following a voltage or Reactive Power schedule, 2) from having its
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VAR-001-4.2 — Voltage and Reactive Control
automatic voltage regulator (AVR) in service or from being in voltage control mode, or 3) from
having to make any notifications, the associated Generator Operator was notified of this
exemption.
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]
5.1. The Transmission Operator shall provide the voltage or Reactive Power schedule (which is
either a range or a target value with an associated tolerance band) 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).
5.2. The Transmission Operator shall provide the Generator Operator with the notification
requirements for deviations from the voltage or Reactive Power schedule (which is either a
range or a target value with an associated tolerance band).
5.3. The Transmission Operator shall provide the criteria used to develop voltage schedules or
Reactive Power schedule (which is either a range or a target value with an associated
tolerance band) to the Generator Operator within 30 days of receiving a request.
M5. The Transmission Operator shall have evidence of a documented voltage or Reactive Power
schedule (which is either a range or a target value with an associated tolerance band).
For part 5.1, the Transmission Operator shall have evidence it provided a voltage or Reactive Power
schedule (which is either a range or a target value with an associated tolerance band) to the
applicable Generator Operators, and that the Generator Operator was directed to comply with the
schedule in automatic voltage control mode, unless exempted.
For part 5.2, the Transmission Operator shall have evidence it provided notification requirements
for deviations from the voltage or Reactive Power schedule (which is either a range or a target
value with an associated tolerance band). For part 5.3, the Transmission Operator shall have
evidence it provided the criteria used to develop voltage schedules or Reactive Power schedule
(which is either a range or a target value with an associated tolerance band) within 30 days of
receiving a request by a Generator Operator.
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]
M6. The Transmission Operator shall have evidence that it provided documentation to the Generator
Owner when a change was needed to a generating unit’s step-up transformer tap in accordance
with the requirement and that it consulted with the Generator Owner.

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VAR-001-4.2 — Voltage and Reactive Control

C. Compliance
1.

Compliance Monitoring Process:

1.1. Compliance Enforcement Authority:
As defined in the NERC Rules of Procedure, “Compliance Enforcement Authority” refers to NERC or
the Regional Entity in their respective roles of monitoring and enforcing compliance with the NERC
Reliability Standards.
1.2. Evidence Retention:
The following evidence retention periods identify the period of time a registered entity is required
to retain specific evidence to demonstrate compliance. For instances in which the evidence
retention period specified below is shorter than the time since the last audit, the Compliance
Enforcement Authority may ask the registered entity to provide other evidence to show that it was
compliant for the full time period since the last audit.
The Transmission Operator shall retain evidence for Measures M1 through M6 for 12 months. The
Compliance Monitor shall retain any audit data for three years.
1.3. Compliance Monitoring and Assessment Processes:
“Compliance Monitoring and Assessment Processes” refers to the identification of the processes
that will be used to evaluate data or information for the purpose of assessing performance or
outcomes with the associated reliability standard.
1.4. Additional Compliance Information:
None

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VAR-001-4.2 — Voltage and Reactive Control
Table of Compliance Elements
R#

Time
Horizon

R1

Operations
Planning

R2

Real-time
Operations,
Same-day
Operations,
and
Operations
Planning

R3

Real-time
Operations,
Same-day
Operations,
and
Operations
Planning

VRF

High

High

High

Violation Severity Levels

Lower VSL

N/A

N/A

N/A

Moderate VSL

High VSL

Severe VSL

N/A

N/A

The Transmission
Operator does not
specify a system
voltage schedule
(which is either a
range or a target
value with an
associated tolerance
band).

N/A

The Transmission
Operator does not
schedule sufficient
reactive resources as
necessary to avoid
violating an SOL.

The Transmission
Operator does not
schedule sufficient
reactive resources as
necessary to avoid
violating an IROL.

N/A

The Transmission
Operator does not
operate or direct any
real-time operation
of devices as
necessary to avoid
violating an SOL.

The Transmission
Operator does not
operate or direct any
real-time operation of
devices as necessary
to avoid violating an
IROL.

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VAR-001-4.2 — Voltage and Reactive Control

R#

R4

Time
Horizon

Operations
Planning

VRF

Lower

Violation Severity Levels

Lower VSL

N/A

Moderate VSL

High VSL

N/A

The Transmission
Operator has
exemption criteria
and notified the
Generator Operator,
but the Transmission
Operator does not
have evidence of the
notification to the
Generator Operator.

Severe VSL

The Transmission
Operator does not
have exemption
criteria.

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VAR-001-4.2 — Voltage and Reactive Control

R#

R5

Time
Horizon

Operations
Planning

VRF

Medium

Violation Severity Levels

Lower VSL

N/A

Moderate VSL

The Transmission
Operator does not
provide the criteria
for voltage or
Reactive Power
schedules (which is
either a range or a
target value with an
associated tolerance
band) after 30 days
of a request.

High VSL

The Transmission
Operator does not
provide voltage or
Reactive Power
schedules (which is
either a range or a
target value with an
associated tolerance
band) to all
Generator
Operators.

Severe VSL
The Transmission
Operator does not
provide voltage or
Reactive Power
schedules (which is
either a range or a
target value with an
associated tolerance
band) to any
Generator Operators.
Or
The Transmission
Operator does not
provide the
Generator Operator
with the notification
requirements for
deviations from the
voltage or Reactive
Power schedule
(which is either a
range or a target
value with an
associated tolerance
band).

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VAR-001-4.2 — Voltage and Reactive Control

R#

R6

Time
Horizon

Operations
Planning

VRF

Lower

Violation Severity Levels

Lower VSL
The Transmission
Operator does not
provide either the
technical justification
or timeframe for
changing generator
step-up tap settings.

Moderate VSL

N/A

High VSL

Severe VSL

N/A

The Transmission
Operator does not
provide the technical
justification and the
timeframe for
changing generator
step-up tap settings.

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VAR-001-4.2 Application Guidelines

D. Regional Variances
The following Interconnection-wide variance shall be applicable in the Western Electricity Coordinating
Council (WECC) and replaces, in their entirety, Requirements R4 and R5. Please note that Requirement
R4 is deleted and R5 is replaced with the following requirements.
Requirements
E.A.13

E.A.14

Each Transmission Operator shall issue any one of the following types of voltage schedules to
the Generator Operators for each of their generation resources that are on-line and part of
the Bulk Electric System within the Transmission Operator Area: [Violation Risk Factor:
Medium] [Time Horizon: Operations Planning and Same-day Operations]
•

A voltage set point with a voltage tolerance band and a specified period.

•

An initial volt-ampere reactive output or initial power factor output with a voltage
tolerance band for a specified period that the Generator Operator uses to establish a
generator bus voltage set point.

•

A voltage band for a specified period.

Each Transmission Operator shall provide one of the following voltage schedule reference
points for each generation resource in its Area to the Generator Operator. [Violation Risk
Factor: Medium] [Time Horizon: Operations Planning and Same-day Operations]
•

The generator terminals.

•

The high side of the generator step-up transformer.

•

The point of interconnection.

•

A location designated by mutual agreement between the Transmission Operator and
Generator Operator.

E.A.15

Each Generator Operator shall convert each voltage schedule specified in Requirement E.A.13
into the voltage set point for the generator excitation system. [Violation Risk Factor: Medium]
[Time Horizon: Operations Planning and Same-day Operations]

E.A.16

Each Generator Operator shall provide its voltage set point conversion methodology from the
point in Requirement E.A.14 to the generator terminals within 30 calendar days of request by
its Transmission Operator. [Violation Risk Factor: Lower] [Time Horizon: Operations Planning]

E.A.17

Each Transmission Operator shall provide to the Generator Operator, within 30 calendar days
of a request for data by the Generator Operator, its transmission equipment data and
operating data that supports development of the voltage set point conversion methodology.
[Violation Risk Factor: Lower] [Time Horizon: Operations Planning]

E.A.18

Each Generator Operator shall meet the following control loop specifications if the Generator
Operator uses control loops external to the automatic voltage regulators (AVR) to manage
Mvar loading: [Violation Risk Factor: Medium] [Time Horizon: Real-time Operations]

E.A.18.1. Each control loop’s design incorporates the AVR’s automatic voltage controlled response to
voltage deviations during System Disturbances.
E.A.18.2. Each control loop is only used by mutual agreement between the Generator Operator and the
Transmission Operator affected by the control loop.
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VAR-001-4.2 Application Guidelines
Measures 1
M.E.A.13 Each Transmission Operator shall have and provide upon request, evidence that it provided
the voltage schedules to the Generator Operator. Dated spreadsheets, reports, voice
recordings, or other documentation containing the voltage schedule including set points,
tolerance bands, and specified periods as required in Requirement E.A.13 are acceptable as
evidence.
M.E.A.14 The Transmission Operator shall have and provide upon request, evidence that it provided
one of the voltage schedule reference points in Requirement E.A.14 for each generation
resource in its Area to the Generator Operator. Dated letters, e-mail, or other documentation
that contains notification to the Generator Operator of the voltage schedule reference point
for each generation resource are acceptable as evidence.
M.E.A.15 Each Generator Operator shall have and provide upon request, evidence that it converted a
voltage schedule as described in Requirement E.A.13 into a voltage set point for the AVR.
Dated spreadsheets, logs, reports, or other documentation are acceptable as evidence.
M.E.A.16 The Generator Operator shall have and provide upon request, evidence that within 30
calendar days of request by its Transmission Operator it provided its voltage set point
conversion methodology from the point in Requirement E.A.14 to the generator terminals.
Dated reports, spreadsheets, or other documentation are acceptable as evidence.
M.E.A.17 The Transmission Operator shall have and provide upon request, evidence that within 30
calendar days of request by its Generator Operator it provided data to support development
of the voltage set point conversion methodology. Dated reports, spreadsheets, or other
documentation are acceptable as evidence.
M.E.A.18 If the Generator Operator uses outside control loops to manage Mvar loading, the Generator
Operator shall have and provide upon request, evidence that it met the control loop
specifications in sub-parts E.A.18.1 through E.A.18.2. Design specifications with identified
agreed-upon control loops, system reports, or other dated documentation are acceptable as
evidence.

1

The number for each measure corresponds with the number for each requirement, i.e. M.E.A.13 means the measure for Requirement E.A.13.

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VAR-001-4.2 Application Guidelines

Violation Severity Levels
E#

Lower VSL

Moderate VSL

High VSL

Severe VSL

E.A.13

For the specified
period, the
Transmission
Operator did not
issue one of the
voltage schedules
listed in E.A.13 to at
least one
generation resource
but less than or
equal to 5% of the
generation
resources that are
on-line and part of
the BES in the
Transmission
Operator Area.

For the specified
period, the
Transmission
Operator did not
issue one of the
voltage schedules
listed in E.A.13 to
more than 5% but
less than or equal to
10% of the
generation
resources that are
on-line and part of
the BES in the
Transmission
Operator Area.

For the specified
period, the
Transmission
Operator did not
issue one of the
voltage schedules
listed in E.A.13 to
more than 10% but
less than or equal to
15% of the
generation
resources that are
on-line and part of
the BES in the
Transmission
Operator Area.

For the specified
period, the
Transmission
Operator did not
issue one of the
voltage schedules
listed in E.A.13 to
more than 15% of
the generation
resources that are
on-line and part of
the BES in the
Transmission
Operator Area.

E.A.14

The Transmission
Operator did not
provide a voltage
schedule reference
point for at least
one but less than or
equal to 5% of the
generation
resources in the
Transmission
Operator area.

The Transmission
Operator did not
provide a voltage
schedule reference
point for more than
5% but less than or
equal to 10% of the
generation
resources in the
Transmission
Operator Area.

The Transmission
Operator did not a
voltage schedule
reference point for
more than 10% but
less than or equal to
15% of the
generation
resources in the
Transmission
Operator Area.

The Transmission
Operator did not
provide a voltage
schedule reference
point for more than
15% of the
generation
resources in the
Transmission
Operator Area.

E.A.15

The Generator
Operator failed to
convert at least one
voltage schedule in
Requirement E.A.13
into the voltage set
point for the AVR
for less than 25% of
the voltage
schedules.

The Generator
Operator failed to
convert the voltage
schedules in
Requirement E.A.13
into the voltage set
point for the AVR
for 25% or more but
less than 50% of the
voltage schedules.

The Generator
Operator failed to
convert the voltage
schedules in
Requirement E.A.13
into the voltage set
point for the AVR
for 50% or more but
less than 75% of the
voltage schedules.

The Generator
Operator failed to
convert the voltage
schedules in
Requirement E.A.13
into the voltage set
point for the AVR
for 75% or more of
the voltage
schedules.

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VAR-001-4.2 Application Guidelines
E#

Lower VSL

Moderate VSL

High VSL

Severe VSL

E.A.16

The Generator
Operator provided
its voltage set
point conversion
methodology
greater than 30
days but less than
or equal to 60
days of a request
by the
Transmission
Operator.

The Generator
Operator provided
its voltage set
point conversion
methodology
greater than 60
days but less than
or equal to 90
days of a request
by the
Transmission
Operator.

The Generator
Operator provided
its voltage set
point conversion
methodology
greater than 90
days but less than
or equal to 120
days of a request
by the
Transmission
Operator.

The Generator
Operator did not
provide its
voltage set point
conversion
methodology
within 120 days of
a request by the
Transmission
Operator.

E.A.17

The Transmission
Operator provided
its data to support
development of
the voltage set
point conversion
methodology than
30 days but less
than or equal to
60 days of a
request by the
Generator
Operator.

The Transmission
Operator provided
its data to support
development of
the voltage set
point conversion
methodology
greater than 60
days but less than
or equal to 90
days of a request
by the Generator.
Operator.

The Transmission
Operator provided
its data to support
development of
the voltage set
point conversion
methodology
greater than 90
days but less than
or equal to 120
days of a request
by the Generator.
Operator.

The Transmission
Operator did not
provide its data to
support
development of
the voltage set
point conversion
methodology
within 120 days of
a request by the
Generator
Operator.

N/A

The Generator
Operator did not
meet the control
loop specifications
in EA18.2 when the
Generator Operator
uses control loop
external to the AVR
to manage Mvar
loading.

The Generator
Operator did not
meet the control
loop specifications
in EA18.1 when the
Generator Operator
uses control loop
external to the AVR
to manage Mvar
loading.

The Generator
Operator did not
meet the control
loop specifications
in EA18.1 through
EA18.2 when the
Generator Operator
uses control loop
external to the AVR
to manage Mvar
loading.

E.A.18

E.

Interpretations
None

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VAR-001-4.2 Application Guidelines
F.

Associated Documents
None.

Version History
Version

Date

Action

Change Tracking

0

April 1, 2005

Effective Date

New

1

August 2, 2006

BOT Adoption

Revised

1

June 18, 2007

FERC approved Version 1 of the standard.

Revised

1

July 3, 2007

Added “Generator Owners” and “Generator
Operators” to Applicability section.

Errata

1

August 23, 2007

Removed “Generator Owners” and “Generator
Operators” to Applicability section.

Errata

2

August 5, 2010

Adopted by NERC Board of Trustees; Modified to
address Order No. 693 Directives contained in
paragraphs 1858 and 1879.

Revised

2

January, 10 2011

FERC issued letter order
approving the addition of LSEs
and Controllable Load to the
standard.

Revised

3

May 9, 2012

Adopted by NERC Board of Trustees; Modified to
add a WECC region variance

Revised

3

June 20, 2013

FERC issued order approving VAR-001-3

Revised

3

November 21,
2013

R5 and associated elements approved by FERC for
retirement as part of the Paragraph 81 project
(Project 2013-02)

Revised

4

February 6, 2014 Adopted by NERC Board of Trustees

4

August 1, 2014

4.1

August 25, 2015

4.1

November 13,
2015
June 14, 2017
August 10, 2017
September 26,
2017

4.2
4.2
4.2

FERC issued letter order issued approving VAR001-4
Added “or” to Requirement R5, 5.3 to read:
schedules or Reactive Power
FERC Letter Order approved errata to VAR-001-4.1.
Docket RD15-6-000
Project 2016-EPR-02 errata recommendations
Adopted by NERC Board of Trustees
FERC Letter Order issued approving VAR-001-4.2
Docket No. RD17-7-000.

Revised

Errata
Errata
Errata
Errata

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VAR-001-4.2 Application Guidelines
Guidelines and Technical Basis
For technical basis for each requirement, please review the rationale provided for each requirement.
Rationale:

During development of this standard, text boxes were embedded within the standard to explain the rationale
for various parts of the standard. Upon BOT approval, the text from the rationale text boxes was moved to this
section.
Rationale for R1:
Paragraph 1868 of Order No. 693 requires NERC to add more "detailed and definitive requirements on
“established limits” and “sufficient reactive resources”, and identify acceptable margins (i.e. voltage and/or
reactive power margins)." Since Order No. 693 was issued, however, several FAC and TOP standards have
become enforceable to add more requirements around voltage limits. More specifically, FAC-011 and FAC-014
require that System Operating Limits (SOLs) and reliability margins are established. The NERC Glossary
definition of SOLs includes both: 1) voltage stability ratings (Applicable pre- and post-Contingency Voltage
Stability) and 2) System Voltage Limits (Applicable pre- and post-Contingency voltage limits). Therefore, for
reliability reasons Requirement R1 now requires a Transmission Operator (TOP) to set voltage or Reactive
Power schedules with associated tolerance bands. Further, since neighboring areas can affect each other
greatly, each TOP must also provide a copy of these schedules to its Reliability Coordinator (RC) and adjacent
TOP upon request.
Rationale for R2:
Paragraph 1875 from Order No. 693 directed NERC to include requirements to run voltage stability analysis
periodically, using online techniques where commercially available and offline tools when online tools are not
available. This standard does not explicitly require the periodic voltage stability analysis because such analysis
would be performed pursuant to the SOL methodology developed under the FAC standards. TOP standards
also require the TOP to operate within SOLs and Interconnection Reliability Operating Limits (IROL). The VAR
standard drafting team (SDT) and industry participants also concluded that the best models and tools are the
ones that have been proven and the standard should not add a requirement for a responsible entity to
purchase new online simulations tools. Thus, the VAR SDT simplified the requirements to ensuring sufficient
reactive resources are online or scheduled. Controllable load is specifically included to answer FERC's directive
in Order No. 693 at Paragraph 1879.
Rationale for R3:
Similar to Requirement R2, the VAR SDT determined that for reliability purposes, the TOP must ensure
sufficient voltage support is provided in Real-time in order to operate within an SOL.
Rationale for R4:
The VAR SDT received significant feedback on instances when a TOP would need the flexibility for defining
exemptions for generators. These exemptions can be tailored as the TOP deems necessary for the specific
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VAR-001-4.2 Application Guidelines
area’s needs. The goal of this requirement is to provide a TOP the ability to exempt a Generator Operator
(GOP) from: 1) a voltage or Reactive Power schedule, 2) a setting on the AVR, or 3) any VAR-002 notifications
based on the TOP’s criteria. Feedback from the industry detailed many system events that would require these
types of exemptions which included, but are not limited to: 1) maintenance during shoulder months, 2)
scenarios where two units are located within close proximity and both cannot be in voltage control mode, and
3) large system voltage swings where it would harm reliability if all GOP were to notify their respective TOP of
deviations at one time. Also, in an effort to improve the requirement, the sub-requirements containing an
exemption list were removed from the currently enforceable standard because this created more compliance
issues with regard to how often the list would be updated and maintained.
Rationale for R5:
The new requirement provides transparency regarding the criteria used by the TOP to establish the voltage
schedule. This requirement also provides a vehicle for the TOP to use appropriate granularity when setting
notification requirements for deviation from the voltage or Reactive Power schedule. Additionally, this
requirement provides clarity regarding a “tolerance band” as specified in the voltage schedule and the control
dead-band in the generator’s excitation system.
Voltage schedule tolerances are the bandwidth that accompanies the voltage target in a voltage schedule,
should reflect the anticipated fluctuation in voltage at the Generation Operator’s facility during normal
operations, and be based on the TOP’s assessment of N‐1 and credible N‐2 system contingencies. The voltage
schedule’s bandwidth should not be confused with the control dead‐band that is programmed into a
Generation Operator’s automatic voltage regulator’s control system, which should be adjusting the AVR prior
to reaching either end of the voltage schedule’s bandwidth.
Rationale for R6:
Although tap settings are first established prior to interconnection, this requirement could not be deleted
because no other standard addresses when a tap setting must be adjusted. If the tap setting is not properly
set, then the amount of VARs produced by a unit can be affected.

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