PRC-002-5

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

A. Introduction
1.

Title:

Disturbance Monitoring and Reporting Requirements

2.

Number:

PRC-002-5

3.

Purpose:

To have adequate data available to facilitate analysis of Bulk Electric
System (BES) Disturbances.

4.

Applicability:
4.1. Functional Entities:
4.1.1. Reliability Coordinator
4.1.2. Transmission Owner
4.1.3. Generator Owner
4.2. Facilities: BES Elements, excluding Inverter-Based Resources. 1

5.

1

Effective Date: See Implementation Plan

Disturbance monitoring and reporting requirements for Inverter-Based Resources are addressed in PRC-028.
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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

B. Requirements and Measures
R1. Each Transmission Owner shall: [Violation Risk Factor: Lower] [Time Horizon: Longterm Planning]
1.1. Identify BES buses for which sequence of events recording (SER) and fault
recording (FR) data is required by using the methodology in PRC-002-5,
Attachment 1.
1.2. Notify the other owners of BES Elements directly connected 2 to those BES buses,
that SER or FR data is required for those BES Elements, only if the Transmission
Owner who identified the BES buses in Part 1.1 does not have SER or FR data.
This notification is required within 90 calendar days of completion of Part 1.1.
1.3. Re-evaluate all BES buses at least once every five calendar years in accordance
with Part 1.1 and notify other owners in accordance with Part 1.2.
M1. The Transmission Owner for Requirement R1, Part 1.1 has a dated (electronic or hard
copy) list of BES buses for which SER and FR data is required, identified in accordance
with PRC-002-5, Attachment 1; has dated (electronic or hard copy) evidence that it
notified other owners in accordance with Requirement R1, Part 1.2; and evidence that
all BES buses have been re-evaluated within the required intervals under Requirement
R1, Part 1.3.
R2. Each Transmission Owner and Generator Owner shall have SER data for circuit breaker
position (open/close) for each circuit breaker it owns directly connected to the BES
buses identified in Requirement R1 and associated with the BES Elements at those BES
buses. [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
M2. The Transmission Owner or Generator Owner has evidence (electronic or hard copy)
of SER data for circuit breaker position as specified in Requirement R2. Evidence may
include, but is not limited to: (1) documents describing the device interconnections
and configurations which may include a single design standard as representative for
common installations; or (2) actual data recordings; or (3) station drawings.
R3. Each Transmission Owner and Generator Owner shall have FR data to determine the
following electrical quantities for each triggered FR for the BES Elements it owns
directly connected to the BES buses identified in Requirement R1: [Violation Risk
Factor: Lower] [Time Horizon: Long-term Planning]
3.1. Phase-to-neutral voltage for each phase of each specified BES bus.
3.2. Each phase current and the residual or neutral current for the following BES
Elements:
3.2.1. Transformers that have a low-side operating voltage of 100 kV or above.
For the purposes of this standard, “directly connected” BES Elements are BES Elements connected at the same
voltage level within the same physical location sharing a common ground grid with the BES bus identified under
Attachment 1. Transformers that have a low-side operating voltage of less than 100 kV are excluded.

2

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

3.2.2. Transmission Lines.
M3. The Transmission Owner or Generator Owner has evidence (electronic or hard copy)
of FR data that is sufficient to determine electrical quantities as specified in
Requirement R3. Evidence may include, but is not limited to: (1) documents describing
the device specifications and configurations which may include a single design
standard as representative for common installations; or (2) actual data recordings or
derivations; or (3) station drawings.
R4. Each Transmission Owner and Generator Owner shall have FR data as specified in
Requirement R3 that meets the following: [Violation Risk Factor: Lower] [Time
Horizon: Long-term Planning]
4.1. A single record or multiple records that include:
•

A pre-trigger record length of at least two cycles and a total record length of
at least 30 cycles for the same trigger point, or

•

At least two cycles of the pre-trigger data, the first three cycles of the posttrigger data, and the final cycle of the fault as seen by the fault recorder.

4.2. A minimum recording rate of 16 samples per cycle.
4.3. Trigger settings for at least the following:
4.3.1. Neutral (residual) overcurrent.
4.3.2. Phase undervoltage or overcurrent.
M4. The Transmission Owner or Generator Owner has evidence (electronic or hard copy)
that FR data meets Requirement R4. Evidence may include, but is not limited to: (1)
documents describing the device specification (R4, Part 4.2) and device configuration
or settings (R4, Parts 4.1 and 4.3), or (2) actual data recordings or derivations.
R5. Each Reliability Coordinator shall: [Violation Risk Factor: Lower] [Time Horizon: Longterm Planning]
5.1. Identify BES Elements for which dynamic Disturbance recording (DDR) data is
required, including the following:
5.1.1. Synchronous generating resource(s) with:
5.1.1.1. Gross individual nameplate rating greater than or equal to 500
MVA.
5.1.1.2. Gross individual nameplate rating greater than or equal to 300
MVA where the gross plant/facility aggregate nameplate rating is
greater than or equal to 1,000 MVA.
5.1.2. Any one BES Element that is part of a stability (angular or voltage) related
System Operating Limit (SOL).

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

5.1.3. Each terminal of a high voltage direct current (HVDC) circuit with a
nameplate rating greater than or equal to 300 MVA, on the alternating
current (AC) portion of the converter.
5.1.4. One or more BES Elements that are part of an Interconnection Reliability
Operating Limit (IROL).
5.1.5. Any one BES Element within a major voltage sensitive area as defined by
an area with an in-service undervoltage load shedding (UVLS) program.
5.2. Identify a minimum DDR coverage, inclusive of those BES Elements identified in
Part 5.1, of at least:
5.2.1. One BES Element; and
5.2.2. One BES Element per 3,000 MW of the Reliability Coordinator’s historical
simultaneous peak System Demand.
5.3. Notify all owners of identified BES Elements, within 90 calendar days of
completion of Part 5.1, that their respective BES Elements require DDR data.
5.4. Re-evaluate all BES Elements within its Reliability Coordinator Area at least once
every five calendar years in accordance with Parts 5.1 and 5.2, and notify owners
in accordance with Part 5.3.
M5. The Reliability Coordinator has a dated (electronic or hard copy) list of BES Elements
for which DDR data is required, developed in accordance with Requirement R5, Part
5.1 and Part 5.2; and re-evaluated in accordance with Part 5.4. The Reliability
Coordinator has dated evidence (electronic or hard copy) that each Transmission
Owner or Generator Owner has been notified in accordance with Requirement 5, Part
5.3. Evidence may include, but is not limited to letters, emails, electronic files, or hard
copy records demonstrating transmittal of information.
R6. Each Transmission Owner shall have DDR data to determine the following electrical
quantities for each BES Element it owns for which it received notification as identified
in Requirement R5: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
6.1. One phase-to-neutral or positive sequence voltage.
6.2. The phase current for the same phase at the same voltage corresponding to the
voltage in Requirement R6, Part 6.1, or the positive sequence current.
6.3. Real Power and Reactive Power flows expressed on a three-phase basis
corresponding to all circuits where current measurements are required.
6.4. Frequency of any one of the voltage(s) in Requirement R6, Part 6.1.
M6. The Transmission Owner has evidence (electronic or hard copy) of DDR data to
determine electrical quantities as specified in Requirement R6. Evidence may include,
but is not limited to: (1) documents describing the device specifications and
configurations, which may include a single design standard as representative for

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

common installations; or (2) actual data recordings or derivations; or (3) station
drawings.
R7. Each Generator Owner shall have DDR data to determine the following electrical
quantities for each BES Element it owns for which it received notification as identified
in Requirement R5: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
7.1. One phase-to-neutral, phase-to-phase, or positive sequence voltage at either the
generator step-up transformer (GSU) high-side or low-side voltage level.
7.2. The phase current for the same phase at the same voltage corresponding to the
voltage in Requirement R7, Part 7.1, phase current(s) for any phase-to-phase
voltages, or positive sequence current.
7.3. Real Power and Reactive Power flows expressed on a three-phase basis
corresponding to all circuits where current measurements are required.
7.4. Frequency of at least one of the voltages in Requirement R7, Part 7.1.
M7. The Generator Owner has evidence (electronic or hard copy) of DDR data to
determine electrical quantities as specified in Requirement R7. Evidence may include,
but is not limited to: (1) documents describing the device specifications and
configurations, which may include a single design standard as representative for
common installations; or (2) actual data recordings or derivations; or (3) station
drawings.
R8. Each Transmission Owner and Generator Owner responsible for DDR data for the BES
Elements identified in Requirement R5 shall have continuous data recording and
storage. If the equipment was installed prior to the effective date of the Reliability
Standard PRC-002-2 3 and is not capable of continuous recording, triggered records
must meet the following: [Violation Risk Factor: Lower] [Time Horizon: Long-term
Planning]
8.1. Triggered record lengths of at least three minutes.
8.2. At least one of the following three triggers:
•

Off nominal frequency trigger set at:
o
o
o
o

•

Low
<59.75 Hz
<59.55 Hz
<59.35 Hz
<58.55 Hz

High
>61.0 Hz
>61.0 Hz
>61.0 Hz
>61.5 Hz

< -0.03125 Hz/sec

>0.125 Hz/sec

Eastern Interconnection
Western Interconnection
ERCOT Interconnection
Quebec Interconnection

Rate of change of frequency trigger set at:
o Eastern Interconnection

The effective date of the Reliability Standard PRC-002-2 in the U.S. was July 1, 2016. The effective date may be
different for other jurisdictions.

3

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

o Western Interconnection
o ERCOT Interconnection
o Quebec Interconnection
•

< -0.05625 Hz/sec
< -0.08125 Hz/sec
< -0.18125 Hz/sec

>0.125 Hz/sec
>0.125 Hz/sec
>0.1875 Hz/sec

Undervoltage trigger set no lower than 85 percent of normal operating
voltage for a duration of 5 seconds.

M8. Each Transmission Owner and Generator Owner has dated evidence (electronic or
hard copy) of data recordings and storage in accordance with Requirement R8.
Evidence may include, but is not limited to: (1) documents describing the device
specifications and configurations, which may include a single design standard as
representative for common installations; or (2) actual data recordings.
R9. Each Transmission Owner and Generator Owner responsible for DDR data for the BES
Elements identified in Requirement R5 shall have DDR data that meet the following:
[Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
9.1. Input sampling rate of at least 960 samples per second.
9.2. Output recording rate of electrical quantities of at least 30 times per second.
M9. The Transmission Owner or Generator Owner has evidence (electronic or hard copy)
that DDR data meets Requirement R9. Evidence may include, but is not limited to: (1)
documents describing the device specification, device configuration, or settings (R9,
Part 9.1; R9, Part 9.2); or (2) actual data recordings (R9, Part 9.2).
R10. Each Transmission Owner and Generator Owner shall time synchronize all SER and FR
data for the BES buses identified in Requirement R1 and DDR data for the BES
Elements identified in Requirement R5 to meet the following: [Violation Risk Factor:
Lower] [Time Horizon: Long-term Planning]
10.1. Synchronization to Coordinated Universal Time (UTC) with or without a local
time offset.
10.2. Synchronized device clock accuracy within ± 2 milliseconds of UTC.
M10. The Transmission Owner or Generator Owner has evidence (electronic or hard copy)
of time synchronization described in Requirement R10. Evidence may include, but is
not limited to: (1) documents describing the device specification, configuration, or
setting; (2) time synchronization indication or status; or 3) station drawings.
R11. Each Transmission Owner and Generator Owner shall provide, upon request, all SER
and FR data for the BES buses identified in Requirement R1 and DDR data for the BES
Elements identified in Requirement R5 to the Reliability Coordinator, Regional Entity,
or NERC in accordance with the following: [Violation Risk Factor: Lower] [Time
Horizon: Long-term Planning]
11.1. Data will be retrievable for the period of 10 calendar days, inclusive of the day
the data was recorded.

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

11.2. Data subject to Part 11.1 will be provided within 30 calendar days of a request
unless an extension is granted by the requestor.
11.3. SER data will be provided in ASCII Comma Separated Value (CSV) format
following Attachment 2.
11.4. FR data will be provided either in CSV format with appropriate headers or in
electronic files that are formatted in conformance with C37.111, IEEE Standard
Common Format for Transient Data Exchange (COMTRADE), revision C37.1111999 or later.
11.5. DDR data will be provided either in CSV format with appropriate headers or in
electronic files that are formatted in conformance with C37.111, IEEE Standard
Common Format for Transient Data Exchange (COMTRADE), revision C37.1111999 or later.
11.6. Data files will be named in conformance with C37.232, IEEE Standard for
Common Format for Naming Time Sequence Data Files (COMNAME), revision
C37.232-2011 or later.
M11. The Transmission Owner or Generator Owner has evidence (electronic or hard copy)
that data was submitted upon request in accordance with Requirement R11. Evidence
may include, but is not limited to: (1) dated transmittals to the requesting entity with
formatted records; (2) documents describing data storage capability, device
specification, configuration, or settings; or (3) actual data recordings.
R12. Each Transmission Owner and Generator Owner shall, upon the discovery of a failure
of the recording capability for the SER, FR or DDR data: [Violation Risk Factor: Lower]
[Time Horizon: Long-term Planning]
•

Restore the recording capability within 90 calendar days, or

•

Submit a Corrective Action Plan (CAP) to the Regional Entity within 90 calendar
days and then implement it according to CAP timeline.

M12. The Transmission Owner or Generator Owner has dated evidence (electronic or hard
copy) that meets Requirement R12. Evidence may include, but is not limited to: (1)
dated reports of discovery of a failure, (2) documentation noting the date the data
recording was restored, (3) SCADA records, or (4) dated CAP transmittals to the
Regional Entity and evidence that it implemented the CAP.
R13. Each Transmission Owner and Generator Owner shall: [Violation Risk Factor: Lower]
[Time Horizon: Long-term Planning]
13.1. Within three (3) calendar years of completing a re-evaluation or receiving
notification under Requirement R1, Part 1.3, have SER or FR data as applicable
for BES Elements directly connected to the identified BES buses.
13.2. Within three (3) calendar years of receiving notification under Requirement R5,
Part 5.4, have DDR data for BES Elements identified during the re-evaluation.

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M13. The Transmission Owner or Generator Owner has dated evidence (electronic or hard
copy) that meets Requirement R13. Evidence may include, but is not limited to:
letters, emails, drawings, or settings files.

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

C. Compliance
1.

Compliance Monitoring Process
1.1. Compliance Enforcement Authority: “Compliance Enforcement Authority”
means NERC or the Regional Entity, or any entity as otherwise designated by an
Applicable Governmental Authority, in their respective roles of monitoring
and/or enforcing compliance with mandatory and enforceable Reliability
Standards in their respective jurisdictions.
1.2. Evidence Retention:
The following evidence retention periods identify the period of time an entity is
required to retain specific evidence to demonstrate compliance. For instances
where the evidence retention period specified below is shorter than the time
since the last audit, the Compliance Enforcement Authority may ask an entity to
provide other evidence to show that it was compliant for the full time period
since the last audit.
The Transmission Owner, Generator Owner, and Reliability Coordinator shall
keep data or evidence to show compliance as identified below unless directed by
its Compliance Enforcement Authority to retain specific evidence for a longer
period of time as part of an investigation:
The Transmission Owner shall retain evidence of Requirement R1, for five
calendar years.
The Reliability Coordinator shall retain evidence of Requirement R5, for five
calendar years.
The Transmission Owner shall retain evidence of Requirement R6, for three
calendar years.
The Generator Owner shall retain evidence of Requirement R7, for three
calendar years.
The Transmission Owner and Generator Owner shall retain evidence of
Requirements R2, R3, R4, R8, R9, R10, R11, and R12, for three calendar years.
The Transmission Owner and Generator Owner as applicable shall retain
evidence of Requirement R13, for five calendar years.
If a Transmission Owner, Generator Owner, or Reliability Coordinator is found
non-compliant, it shall keep information related to the non-compliance until
mitigation is completed and approved or for the time specified above, whichever
is longer.
The Compliance Enforcement Authority shall keep the last audit records, and all
requested and submitted subsequent audit records.
1.3. Compliance Monitoring and Enforcement Program: As defined in the NERC
Rules of Procedure, “Compliance Monitoring and Enforcement Program” refers
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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

to the identification of the processes that will be used to evaluate data or
information for the purpose of assessing performance or outcomes with
associated Reliability Standard.

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

Violation Severity Levels
Violation Severity Levels

R#

R1

Lower VSL

Moderate VSL

High VSL

Severe VSL

The Transmission Owner
identified the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3 for
more than 80 percent, but
less than 100 percent of
the required BES buses
that they own.

The Transmission Owner
identified the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3 for
more than 70 percent, but
less than or equal to 80
percent of the required BES
buses that they own.

The Transmission Owner
identified the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3 for
more than 60 percent, but
less than or equal to 70
percent of the required
BES buses that they own.

The Transmission Owner
identified the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3 for
less than or equal to 60
percent of the required
BES buses that they own.

OR

OR

OR

The Transmission Owner
evaluated the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3, but
was late by 30 calendar
days or less.

The Transmission Owner
evaluated the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3, but
was late by greater than 30
calendar days and less than
or equal to 60 calendar
days.

The Transmission Owner
evaluated the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3, but
was late by greater than
60 calendar days and less
than or equal to 90
calendar days.

The Transmission Owner
evaluated the BES buses as
directed by Requirement
R1, Part 1.1 or Part 1.3, but
was late by greater than
90 calendar days.

OR

OR

The Transmission Owner as
directed by Requirement
R1, Part 1.2 was late in
notifying the other owners
that their BES Elements
require SER or FR data by
greater than 10 calendar

The Transmission Owner
as directed by
Requirement R1, Part 1.2
was late in notifying the
other owners that their
BES Elements require SER
or FR data by greater than

OR
The Transmission Owner
as directed by
Requirement R1, Part 1.2
was late in notifying the
other owners that their
BES Elements require SER
or FR data by 10 calendar
days or less.

OR

OR
The Transmission Owner
as directed by
Requirement R1, Part 1.2
was late in notifying one or
more other owners that
their BES Elements require
SER or FR data by greater
than 30 calendar days.

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

R#

Violation Severity Levels
Lower VSL

Moderate VSL

High VSL

days, but less than or equal
to 20 calendar days.

20 calendar days, but less
than or equal to 30
calendar days.

Severe VSL

R2

Each Transmission Owner
or Generator Owner as
directed by Requirement
R2 had more than 80
percent, but less than 100
percent of the total SER
data for circuit breaker
position (open/close) for
each of the circuit breakers
at the BES buses identified
in Requirement R1.

Each Transmission Owner
or Generator Owner as
directed by Requirement R2
had more than 70 percent,
but less than or equal to 80
percent of the total SER
data for circuit breaker
position (open/close) for
each of the circuit breakers
at the BES buses identified
in Requirement R1.

Each Transmission Owner
or Generator Owner as
directed by Requirement
R2 had more than 60
percent but less than or
equal to 70 percent of the
total SER data for circuit
breaker position
(open/close) for each of
the circuit breakers at the
BES buses identified in
Requirement R1.

Each Transmission Owner
or Generator Owner as
directed by Requirement
R2 for less than or equal to
60 percent of the total SER
data for circuit breaker
position (open/close) for
each of the circuit breakers
at the BES buses identified
in Requirement R1.

R3

The Transmission Owner
or Generator Owner had
FR data as directed by
Requirement R3, Parts 3.1
and 3.2 that covers more
than 80 percent, but less
than 100 percent of the
total required electrical
quantities, which is the
product of the total
number of monitored BES

The Transmission Owner or
Generator Owner had FR
data as directed by
Requirement R3, Parts 3.1
and 3.2 that covers more
than 70 percent, but less
than or equal to 80 percent
of the total required
electrical quantities, which
is the product of the total
number of monitored BES

The Transmission Owner
or Generator Owner had
FR data as directed by
Requirement R3, Parts 3.1
and 3.2 that covers more
than 60 percent, but less
than or equal to 70
percent of the total
required electrical
quantities, which is the
product of the total

The Transmission Owner
or Generator Owner had
FR data as directed by
Requirement R3, Parts 3.1
and 3.2 that covers less
than or equal to 60
percent of the total
required electrical
quantities, which is the
product of the total
number of monitored BES

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

Violation Severity Levels

R#

Lower VSL

Moderate VSL

High VSL

Severe VSL

Elements and the number
of specified electrical
quantities for each BES
Element.

Elements and the number
of specified electrical
quantities for each BES
Element.

number of monitored BES
Elements and the number
of specified electrical
quantities for each BES
Element.

Elements and the number
of specified electrical
quantities for each BES
Element.

R4

The Transmission Owner
or Generator Owner had
FR data that meets more
than 80 percent, but less
than 100 percent of the
total recording parameters
as specified in
Requirement R4.

The Transmission Owner or
Generator Owner had FR
data that meets more than
70 percent, but less than or
equal to 80 percent of the
total recording parameters
as specified in Requirement
R4.

The Transmission Owner
or Generator Owner had
FR data that meets more
than 60 percent, but less
than or equal to 70
percent of the total
recording parameters as
specified in Requirement
R4.

The Transmission Owner
or Generator Owner had
FR data that meets less
than or equal to 60
percent of the total
recording parameters as
specified in Requirement
R4.

R5

The Reliability Coordinator
identified the BES
Elements for which DDR
data is required as
directed by Requirement
R5 for more than 80
percent, but less than 100
percent of the required
BES Elements included in
Part 5.1.

The Reliability Coordinator
identified the BES Elements
for which DDR data is
required as directed by
Requirement R5 for more
than 70 percent, but less
than or equal to 80 percent
of the required BES
Elements included in Part
5.1.

The Reliability Coordinator
identified the BES
Elements for which DDR
data is required as
directed by Requirement
R5 for more than 60
percent, but less than or
equal to 70 percent of the
required BES Elements
included in Part 5.1.

The Reliability Coordinator
identified the BES
Elements for which DDR
data is required as
directed by Requirement
R5 for less than or equal to
60 percent of the required
BES Elements included in
Part 5.1.

OR

OR

OR

OR

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

Violation Severity Levels

R#

Lower VSL

Moderate VSL

High VSL

Severe VSL

The Reliability Coordinator
identified the BES
Elements for DDR as
directed by Requirement
R5, Part 5.1 or Part 5.4, but
was late by 30 calendar
days or less.

The Reliability Coordinator
identified the BES Elements
for DDR as directed by
Requirement R5, Part 5.1 or
Part 5.4, but was late by
greater than 30 calendar
days and less than or equal
to 60 calendar days.

The Reliability Coordinator
identified the BES
Elements for DDR as
directed by Requirement
R5, Part 5.1 or Part 5.4, but
was late by greater than
60 calendar days and less
than or equal to 90
calendar days.

The Reliability Coordinator
identified the BES
Elements for DDR as
directed by Requirement
R5, Part 5.1 or Part 5.4, but
was late by greater than
90 calendar days.

OR

R6

The Reliability Coordinator
as directed by
Requirement R5, Part 5.3
was late in notifying the
owners that their BES
Elements require DDR data
by 10 calendar days or
less.

OR
The Reliability Coordinator
as directed by Requirement
R5, Part 5.3 was late in
notifying the owners that
their BES Elements require
DDR data by greater than
10 calendar days, but less
than or equal to 20
calendar days.

OR

The Transmission Owner
had DDR data as directed
by Requirement R6, Parts
6.1 through 6.4 that

The Transmission Owner
had DDR data as directed
by Requirement R6, Parts
6.1 through 6.4 for more

The Transmission Owner
had DDR data as directed
by Requirement R6, Parts
6.1 through 6.4 for more

OR

The Reliability Coordinator
as directed by
The Reliability Coordinator Requirement R5, Part 5.3
as directed by
was late in notifying one or
more owners that their
Requirement R5, Part 5.3
BES Elements require DDR
was late in notifying the
data by greater than 30
owners that their BES
Elements require DDR data calendar days.
by greater than 20
OR
calendar days, but less
The Reliability Coordinator
than or equal to 30
failed to ensure a
calendar days.
minimum DDR coverage
per Part 5.2.
The Transmission Owner
had DDR data as directed
by Requirement R6, Parts
6.1 through 6.4 for less

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PRC-002-5 – Disturbance Monitoring and Reporting Requirements

R#

R7

Violation Severity Levels
Lower VSL

Moderate VSL

High VSL

Severe VSL

covered more than 80
percent, but less than 100
percent of the total
required electrical
quantities, which is the
product of the total
number of applicable BES
Elements and the number
of specified electrical
quantities for each
applicable BES Element.

than 70 percent, but less
than or equal to 80 percent
of the total required
electrical quantities, which
is the product of the total
number of applicable BES
Elements and the number
of specified electrical
quantities for each
applicable BES Element.

than 60 percent, but less
than or equal to 70
percent of the total
required electrical
quantities, which is the
product of the total
number of applicable BES
Elements and the number
of specified electrical
quantities for each
applicable BES Element.

than 60 percent of the
total required electrical
quantities, which is the
product of the total
number of applicable BES
Elements and the number
of specified electrical
quantities for each
applicable BES Element.

The Generator Owner had
DDR data as directed by
Requirement R7, Parts 7.1
through 7.4 that covers
more than 80 percent, but
less than 100 percent of
the total required
electrical quantities, which
is the product of the total
number of applicable BES
Elements and the number
of specified electrical
quantities for each
applicable BES Element.

The Generator Owner had
DDR data as directed by
Requirement R7, Parts 7.1
through 7.4 for more than
70 percent, but less than or
equal to 80 percent of the
total required electrical
quantities, which is the
product of the total number
of applicable BES Elements
and the number of
specified electrical
quantities for each
applicable BES Element.

The Generator Owner had
DDR data as directed by
Requirement R7, Parts 7.1
through 7.4 for more than
60 percent, but less than
or equal to 70 percent of
the total required
electrical quantities, which
is the product of the total
number of applicable BES
Elements and the number
of specified electrical
quantities for each
applicable BES Element.

The Generator Owner had
DDR data as directed by
Requirement R7, Parts 7.1
through 7.4 for less than
60 percent of the total
required electrical
quantities, which is the
product of the total
number of applicable BES
Elements and the number
of specified electrical
quantities for each
applicable BES Element.

Page 15 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

R#

Violation Severity Levels
Lower VSL

Moderate VSL

High VSL

Severe VSL

R8

The Transmission Owner
or Generator Owner had
continuous or noncontinuous DDR data, as
directed in Requirement
R8, for more than 80
percent, but less than 100
percent of the BES
Elements they own as
determined in
Requirement R5.

The Transmission Owner or
Generator Owner had
continuous or noncontinuous DDR data, as
directed in Requirement R8,
for more than 70 percent,
but less than or equal to 80
percent of the BES
Elements they own as
determined in Requirement
R5.

The Transmission Owner
or Generator Owner had
continuous or noncontinuous DDR data, as
directed in Requirement
R8, for more than 60
percent, but less than or
equal to 70 percent of the
BES Elements they own as
determined in
Requirement R5.

The Transmission Owner
or Generator Owner failed
to have continuous or noncontinuous DDR data, as
directed in Requirement
R8, for the BES Elements
they own as determined in
Requirement R5.

R9

The Transmission Owner
or Generator Owner had
DDR data that meets more
than 80 percent, but less
than 100 percent of the
total recording properties
as specified in
Requirement R9.

The Transmission Owner or
Generator Owner had DDR
data that meets more than
70 percent, but less than or
equal to 80 percent of the
total recording properties
as specified in Requirement
R9.

The Transmission Owner
or Generator Owner had
DDR data that meets more
than 60 percent, but less
than or equal to 70
percent of the total
recording properties as
specified in Requirement
R9.

The Transmission Owner
or Generator Owner had
DDR data that meets less
than or equal to 60
percent of the total
recording properties as
specified in Requirement
R9.

R10

The Transmission Owner
or Generator Owner had
time synchronization per
Requirement R10, Parts
10.1 and 10.2 for SER, FR,
and DDR data for more

The Transmission Owner or
Generator Owner had time
synchronization per
Requirement R10, Parts
10.1 and 10.2 for SER, FR,
and DDR data for more

The Transmission Owner
or Generator Owner had
time synchronization per
Requirement R10, Parts
10.1 and 10.2 for SER, FR,
and DDR data for more

The Transmission Owner
or Generator Owner failed
to have time
synchronization per
Requirement R10, Parts
10.1 and 10.2 for SER, FR,
Page 16 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

Violation Severity Levels

R#

R11

Lower VSL

Moderate VSL

High VSL

Severe VSL

than 90 percent, but less
than 100 percent of the
BES buses identified in
Requirement R1 and BES
Elements identified in
Requirement R5 as
directed by Requirement
R10.

than 80 percent, but less
than or equal to 90 percent
of the BES buses identified
in Requirement R1 and BES
Elements identified in
Requirement R5 as directed
by Requirement R10.

than 70 percent, but less
than or equal to 80
percent of the BES buses
identified in Requirement
R1 and BES Elements
identified in Requirement
R5 as directed by
Requirement R10.

and DDR data for less than
or equal to 70 percent of
the BES buses identified in
Requirement R1 and BES
Elements identified in
Requirement R5 as
directed by Requirement
R10.

The Transmission Owner
or Generator Owner as
directed by Requirement
R11, Part 11.2 provided
the requested data more
than one to 10 calendar
days late.

The Transmission Owner or
Generator Owner as
directed by Requirement
R11, Part 11.2 provided the
requested data more than
11 to 20 calendar days late.

The Transmission Owner
or Generator Owner as
directed by Requirement
R11, Part 11.2 provided
the requested data more
than 21 to 30 calendar
days late.

The Transmission Owner
or Generator Owner as
directed by Requirement
R11, Part 11.2 provided
the requested data more
than 30 calendar days late.

OR

The Transmission Owner or
Generator Owner as
directed by Requirement
R11 provided more than 80
percent, but less than or
equal to 90 percent of the
requested data.

OR

The Transmission Owner
or Generator Owner as
directed by Requirement
R11 failed to provide less
than or equal to 70
percent of the requested
data.

The Transmission Owner
or Generator Owner as
directed by Requirement
R11 provided more than
90 percent, but less than
100 percent of the
requested data.
OR

OR

OR
The Transmission Owner or
Generator Owner as

The Transmission Owner
or Generator Owner as
directed by Requirement
R11 provided more than
70 percent, but less than
or equal to 80 percent of
the requested data.
OR

OR

OR
The Transmission Owner
or Generator Owner as

Page 17 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

R#

R12

Violation Severity Levels
Lower VSL

Moderate VSL

High VSL

Severe VSL

The Transmission Owner
or Generator Owner as
directed by Requirement
R11, Parts 11.3 through
11.6 provided more than
90 percent of the data, but
less than 100 percent of
the data in the proper data
format.

directed by Requirement
R11, Parts 11.3 through
11.6 provided more than 80
percent of the data, but less
than or equal to 90 percent
of the data in the proper
data format.

The Transmission Owner
or Generator Owner as
directed by Requirement
R11, Parts 11.3 through
11.6 provided more than
70 percent of the data, but
less than or equal to 80
percent of the data in the
proper data format.

directed by Requirement
R11, Parts 11.3 through
11.6 provided less than or
equal to 70 percent of the
data in the proper data
format.

The Transmission Owner
or Generator Owner as
directed by Requirement
R12 reported a failure and
provided a Corrective
Action Plan to the Regional
Entity more than 90
calendar days, but less
than or equal to 100
calendar days after
discovery of the failure.

The Transmission Owner or
Generator Owner as
directed by Requirement
R12 reported a failure and
provided a Corrective
Action Plan to the Regional
Entity more than 100
calendar days, but less than
or equal to 110 calendar
days after discovery of the
failure.

The Transmission Owner
or Generator Owner as
directed by Requirement
R12 reported a failure and
provided a Corrective
Action Plan to the Regional
Entity more than 110
calendar days, but less
than or equal to 120
calendar days after
discovery of the failure.

The Transmission Owner
or Generator Owner as
directed by Requirement
R12 failed to report a
failure and provide a
Corrective Action Plan to
the Regional Entity more
than 120 calendar days
after discovery of the
failure.

OR

Transmission Owner or
Generator Owner as
directed by Requirement
R12 failed to restore the
recording capability and

The Transmission Owner
or Generator Owner as
directed by Requirement
R12 submitted a CAP to

OR

Page 18 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

R#

R13

Violation Severity Levels
Lower VSL

Moderate VSL

The Transmission Owner or
Generator Owner had data,
as applicable, for the BES
buses identified during the
re-evaluation per
Requirement R1, Part 1.3
and was late by less than or
equal to 6 months.
OR
The Transmission Owner or
Generator Owner had data,
as applicable, for the BES
Elements identified during
the re-evaluation per
Requirement R5, Part 5.4
and was late by less than or
equal to 6 months.

High VSL

Severe VSL

the Regional Entity but
failed to implement it.

failed to submit a CAP to
the Regional Entity.

The Transmission Owner
or Generator Owner had
data, as applicable, for the
BES buses identified during
the re-evaluation per
Requirement R1, Part 1.3
and was late by greater
than 6 months but less
than or equal to 12
months.

The Transmission Owner
or Generator Owner had
data, as applicable, for the
BES buses identified during
the re-evaluation per
Requirement R1, Part 1.3
and was late by greater
than 12 months.

OR
The Transmission Owner
or Generator Owner had
data, as applicable, for the
BES Elements identified
during the re-evaluation
per Requirement R5, Part
5.4 and was late by greater
than 6 months but less
than or equal to 12
months.

OR
The Transmission Owner
or Generator Owner had
data, as applicable, for the
BES Elements identified
during the re-evaluation
per Requirement R5, Part
5.4 and was late by greater
than 12 months.

Page 19 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

D. Regional Variances
None.

E. Interpretations
None.

F. Associated Documents

NERC Reliability Standard PRC-002-5: Implementation Plan.

G. References

IEEE C37.111: Common format for transient data exchange (COMTRADE) for power
Systems.
IEEE C37.232-2011, IEEE Standard for Common Format for Naming Time Sequence Data
Files (COMNAME). Standard published 11/09/2011 by IEEE.
NERC Reliability Standard PRC-002-5: Technical Rationale.

NPCC SP6 Report Synchronized Event Data Reporting, revised March 31, 2005.
U.S.-Canada Power System Outage Task Force, Final Report on the August 14, 2003,
Blackout in the United States and Canada: Causes and Recommendations (2004).
U.S.-Canada Power System Outage Task Force Interim Report: Causes of the August 14th
Blackout in the United States and Canada (Nov. 2003).

Page 20 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

Version History
Version

Date

Action

Change
Tracking

0

February 8, 2005

Adopted by NERC Board of Trustees

New

1

August 2, 2006

Adopted by NERC Board of Trustees

Revised
Revised under
Project 2007-11
and merged with
PRC-018-1.

2

November 13, 2014

Adopted by NERC Board of Trustees

2

September 24, 2015

FERC approved PRC-005-4. Docket No. RM154-000; Order No. 814

3

May 13, 2021

Adopted by NERC Board of Trustees

Revised

4

February 16, 2023

Adopted by NERC Board of Trustees

Revised under
Project 2021-04

4

April 14, 2023

FERC Oder Approving PRC-002-4 Docket No.
RD23-4-000.

4

April 14, 2023

Effective Date

April 1, 2024

5

October 8, 2024

Adopted by NERC Board of Trustees

Revised under
Project 2021-04

5

February 20, 2025

FERC approved PRC-002-5. Docket Nos.
RD25-1-000 and RD25-2-000

Page 21 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

Attachment 1
Methodology for Selecting Buses for Capturing Sequence of Events Recording (SER) and Fault
Recording (FR) Data
(Requirement R1)
To identify monitored Bulk Electric System (BES) buses for SER and FR data required by
Requirement 1, each Transmission Owner shall follow sequentially, unless otherwise noted,
the steps listed below:
Step 1.

Determine a complete list of BES buses that it owns. Refer to section 4.2
Facilities for exclusion.
For the purposes of this standard, a single BES bus includes physical buses with
breakers connected at the same voltage level within the same physical location
sharing a common ground grid. These buses may be modeled or represented by
a single node in fault studies. For example, ring bus or breaker-and-a-half bus
configurations are considered to be a single bus.

Step 2.

Reduce the list to those BES buses that have a maximum available calculated
three-phase short circuit MVA of 1,500 MVA or greater. If there are no buses on
the resulting list, proceed to Step 7.

Step 3.

Determine the 11 BES buses on the list with the highest maximum available
calculated three-phase short circuit MVA level. If the list has 11 or fewer buses,
proceed to Step 7.

Step 4.

Calculate the median MVA level of the 11 BES buses determined in Step 3.

Step 5.

Multiply the median MVA level determined in Step 4 by 20 percent.

Step 6.

Reduce the BES buses on the list to only those that have a maximum available
calculated three-phase short circuit MVA higher than the greater of:

Step 7.

•

1,500 MVA or

•

20 percent of median MVA level determined in Step 5.

If there are no BES buses on the list: the procedure is complete, and no FR and
SER data will be required. Proceed to Step 9.
If the list has 1 or more but less than or equal to 11 BES buses: FR and SER data is
required at the BES bus with the highest maximum available calculated threephase short circuit MVA as determined in Step 3.
During re-evaluation per Requirement R1, Part 1.3, if the three-phase short
circuit MVA of the newly identified BES bus is within 15% of the three-phase
short circuit MVA of the currently applicable BES bus with SER and FR data then
it is not necessary to change the applicable BES bus. Proceed to Step 9.
If the list has more than 11 BES buses: SER and FR data is required on at least the
10 percent of the BES buses determined in Step 6 with the highest maximum
Page 22 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

available calculated three-phase short circuit MVA. Proceed to Step 8.
Step 8.

SER and FR data is required at additional BES buses on the list determined in
Step 6. The aggregate of the number of BES buses determined in Step 7 and this
Step will be at least 20 percent of the BES buses determined in Step 6.
The additional BES buses are selected, at the Transmission Owner’s discretion, to
provide maximum wide-area coverage for SER and FR data. The following BES
bus locations are recommended:

Step 9.

•

Electrically distant buses or electrically distant from other Disturbance
Monitoring Equipment (DME) devices.

•

Voltage sensitive areas.

•

Cohesive load and generation zones.

•

BES buses with a relatively high number of incident Transmission circuits.

•

BES buses with reactive power devices.

•

Major Facilities interconnecting outside the Transmission Owner’s area.

The list of monitored BES buses for SER and FR data for Requirement R1 is the
aggregate of the BES buses determined in Steps 7 and 8.

Page 23 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

Attachment 2
Sequence of Events Recording (SER) Data Format
(Requirement R11, Part 11.3)
Date, Time, Local Time Code, Substation, Device, State 4
08/27/13, 23:58:57.110, -5, Sub 1, Breaker 1, Close
08/27/13, 23:58:57.082, -5, Sub 2, Breaker 2, Close
08/27/13, 23:58:47.217, -5, Sub 1, Breaker 1, Open
08/27/13, 23:58:47.214, -5, Sub 2, Breaker 2, Open

4

“OPEN” and “CLOSE” are used as examples. Other terminology such as TRIP, TRIP TO LOCKOUT, RECLOSE, etc. is also
acceptable.

Page 24 of 25

PRC-002-5 – Disturbance Monitoring and Reporting Requirements

High Level Requirement Overview

Requirement

Entity

Identify
BES Buses

Notification

SER

FR

5 Year
Re-evaluation

R1

TO

X

X

X

X

X

R2

TO | GO

R3

TO | GO

X

R4

TO | GO

X

X

Requirement

Entity

Identify
BES
Elements

R5

RC

X

R6

TO

X

R7

GO

X

R8

TO | GO

X

R9

TO | GO

X

Requirement

Entity

Time
Synchronization

R10

TO | GO

X

R11

TO | GO

R12

TO | GO

Requirement

Entity

Implementation

R13

TO | GO

X

Notification

DDR

5 Year Re-evaluation

X

X

X

Provide SER,
FR, DDR Data

SER, FR, DDR
Availability

X
X

Page 25 of 25