Reliability Standard Audit Worksheet1
PRC-002-NPCC-01 - Disturbance Monitoring
Registered Entity:
NCR Number:
Applicable Function(s): TO, GO, RC
Compliance Assessment Date:
This section must be completed by the Compliance Enforcement Authority.
Compliance Monitoring Method:
Names of Auditors:
1
NPCC developed this Reliability Standard Audit Worksheet (RSAW) language in order to facilitate NERC’s and the Regional Entities’ assessment of a
registered entity’s compliance with this Regional Reliability Standard. The NPCC RSAW language is written to specific versions of each NPCC Regional
Reliability Standard. Entities using this RSAW should choose the version of the RSAW applicable to the Regional Reliability Standard being assessed. While
the information included in this RSAW provides some of the methodology that NPCC has elected to use to assess compliance with the requirements of the
Regional Reliability Standard, this document should not be treated as a substitute for the Regional Reliability Standard or viewed as additional Regional
Reliability Standard requirements.
In all cases, the Regional Entity should rely on the language contained in the Regional Reliability Standard itself, and not on the language contained in this
RSAW, to determine compliance with the Regional Reliability Standard. NPCC’s Reliability Standards can be found on NERC’s website at
http://www.nerc.com/page.php?cid=2|20 and NPCC’s website at https://www.npcc.org/Standards/SitePages/ApprovedStandardsList.aspx. Additionally,
NPCC Reliability Standards may be updated occasionally , and this RSAW may not necessarily be updated with the same frequency. Therefore, it is
imperative that entities treat this RSAW as a reference document only, and not as a substitute or replacement for the Regional Reliability Standard. It is
the responsibility of the registered entity to verify its compliance with the latest approved version of the Regional Reliability Standards, by the applicable
governmental authority, relevant to its registration status.
The NPCC RSAW language contained within this document provides a non-exclusive list, for informational purposes only, of examples of the types of
evidence a registered entity may produce or may be asked to produce to demonstrate compliance with the Regional Reliability Standard. A registered
entity’s adherence to the examples contained within this RSAW does not necessarily constitute compliance with the applicable Regional Reliability
Standard, and NERC and the Regional Entity using this RSAW reserves the right to request additional evidence from the registered entity that is not
included in this RSAW. Additionally, this RSAW includes excerpts from FERC Orders and other regulatory references. The FERC Order cites are provided
for ease of reference only, and this document does not necessarily include all applicable Order provisions. In the event of a discrepancy between FERC
Orders, and the language included in this document, FERC Orders shall prevail.
Page 1 of 45
Subject Matter Experts
Identify Subject Matter Expert(s) responsible for this Reliability Standard. (Insert additional rows if
necessary)
Registered Entity Response (Required):
SME Name
Title
Organization
Requirement(s)
R1 Supporting Evidence and Documentation
R1. Each Transmission Owner and Generator Owner shall provide Sequence of Event (SOE) recording
capability by installing Sequence of Event recorders or as part of another device, such as a Supervisory
Control And Data Acquisition (SCADA) Remote Terminal Unit (RTU), a generator plant Digital (or
Distributed) Control System (DCS) or part of Fault recording equipment. This capability shall:
[Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
1.1 Be provided at all substations and at locations where circuit breaker operation affects continuity of
service to radial Loads greater than 300MW, or the operation of which drops 50MVA Nameplate
Rating or greater of Generation, or the operation of which creates a Generation/Load island.
Be provided at generating units above 50MVA Nameplate Rating or series of generating units
utilizing a control scheme such that the loss of 1 unit results in a loss of greater than 50MVA
Nameplate Capacity, and at Generating Plants above 300MVA Name Plate Capacity.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
1.2 Monitor the following at each location listed in 1.1:
1.2.1 Transmission and Generator circuit breaker positions
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
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1.2.2 Protective Relay tripping for all Protection Groups that operate to trip circuit breakers
identified in 1.2.1.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
1.2.3 Teleprotection keying and receive
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R1
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
Provided Sequence of Event (SOE) recording capability by installing:
 Sequence of Event recorders or
 as part of another device, such as
o Supervisory Control And Data Acquisition (SCADA),
o Remote Terminal Unit (RTU),
o a generator plant Digital (or Distributed) Control System (DCS)
o part of Fault recording equipment
Provided SOE capability at:
 all A10 substations
Page 3 of 45

at locations where circuit breaker operation affects continuity of service to radial Loads
greater than 300MW.
o Whether the load is continuous or periodic is immaterial. If continuity of service to
greater than 300MW can be affected, SOE recording capability must be provided.
 at locations where circuit breaker operation drops 50MVA Nameplate Rating or greater of
Generation
 at locations where circuit breaker operation creates a Generation/Load island
Provided SOE capability at:
 generating units above 50MVA Nameplate Rating or series of generating units utilizing a
control scheme such that the loss of 1 unit results in a loss of greater than 50MVA Nameplate
Capacity
o The term “control scheme” is not solely applied to protection and extends to the
physical configuration and design limitations under various operating conditions that
can result in the loss of generation greater than 50 MVA Nameplate Capacity.
 at Generating Plants above 300MVA Nameplate Capacity
Monitor the following at each location listed in R1.1:
 Transmission and Generator circuit breaker positions
 Protective Relay tripping for all Protection Groups that operate to trip circuit breakers
identified in R1.2.1.
o If one or more Protective Relays, that form one Protection Group, perform tripping
solely via the lockout relay, then SOE from the lockout relay is sufficient to satisfy
the requirement.
 Teleprotection keying and receive.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R1 of this standard. If Audit Period start date is
prior to October 20, 2015, refer to Webinar slides 9, and 11 through 14, for explanation and
examples of partial implementation requirements.
For GO, SOE capability must be provided if the MVA criteria is met.
For TO, SOE capability must be provided if element is associated with A10 busses.
Auditor Notes:
R2 Supporting Evidence and Documentation
R2. Each Transmission Owner shall provide Fault recording capability for the following Elements at
facilities where Fault recording equipment is required to be installed as per R3: [Violation Risk Factor:
Medium][Time Horizon: Planning and Operations Planning]
R2.1. All transmission lines.
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Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
R2.2. Autotransformers or phase-shifters connected to busses.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
R2.3. Shunt capacitors, shunt reactors.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
R2.4. Individual generator line interconnections.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
R2.5. Dynamic VAR Devices.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
R2.6. HVDC terminals.
Page 5 of 45
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R2
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
Transmission Owner has provided Fault recording capability for the following Elements at facilities
where Fault recording equipment is required to be installed including:
 All transmission lines.
 Autotransformers or phase-shifters connected to busses.
 Shunt capacitors, shunt reactors.
 Individual generator line interconnections.
 Dynamic VAR Devices.
 HVDC terminals.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R2 of this standard.
For TO, applies to elements connected to A10 busses only.
Auditor Notes:
R3 Supporting Evidence and Documentation
R3. Each Transmission Owner shall have Fault recording capability that determines the Current Zero
Time for loss of Bulk Electric System (BES) transmission Elements. [Violation Risk Factor: Medium]
[Time Horizon: Planning and Operations Planning]
Page 6 of 45
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R3
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
o Transmission Owner shall have Fault recording capability that determines the Current Zero
Time for loss of Bulk Electric System (BES) transmission Elements.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R3 of this standard.
 The pool of NPCC BES Assets in scope is the NPCC A10 List of Transmission Elements PLUS
Generation that meets CGS-002 [Ref. Webinar]
 Newly defined BES elements as a result of the revised BES definition will be addressed by CGS005. [Ref. Webinar]
 Current Zero is defined in the NERC Glossary of Terms
Auditor Notes:
R4 Supporting Evidence and Documentation
R4. Each Generator Owner shall provide Fault recording capability for Generating Plants at and above
200
Page 7 of 45
MVA Capacity and connected through a generator step up (GSU) transformer to a Bulk Electric
System Element unless Fault recording capability is already provided by the Transmission Owner.
[Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Question: Did the Generator Owner have Fault recording capability for Generating Plants meeting the
conditions listed above, provided by the Transmission Owner? If yes, provide a list of the Generating
Plants for which the Transmission Owner has provided required Fault recording capability for the
Generator Owner.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R4
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(GO) provided Fault recording capability for Generating Plants at and above 200 MVA Capacity and
connected through a generator step up (GSU) transformer to a Bulk Electric System Element unless
Fault recording capability is already provided by the Transmission Owner (TO). (See next item)
(GO) responded to the applicability Question with response “Yes” and provided list of generating
plants?
If “Yes” review documentation confirming that fault recording capability for listed Generating Plants
are being provided by the Transmission Owner.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R4 of this standard.
Page 8 of 45
For GO, Fault recording capability must be provided when both of the following conditions exist:
 MVA threshold
 Facility is connected through GSU to A10 bus or a circuit that connects to an A10 bus.
Auditor Notes:
R5 Supporting Evidence and Documentation
R5. Each Transmission Owner and Generator Owner shall record for Faults, sufficient electrical
quantities
for each monitored Element to determine the following: [Violation Risk Factor: Medium] [Time
Horizon: Planning and Operations Planning]
5.1 Three phase-to-neutral voltages. (Common bus-side voltages may be used for lines.)
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
5.2 Three phase currents and neutral currents.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
5.3 Polarizing currents and voltages, if used.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Page 9 of 45
5.4 Frequency.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
5.5 Real and reactive power.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R5
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
Transmission Owner and Generator Owner shall record for Faults, sufficient electrical quantities
for each monitored Element to determine the following:
 Three phase-to-neutral voltages. (Common bus-side voltages may be used for lines.)
 Three phase currents and neutral currents.
 Polarizing currents and voltages, if used.
 Frequency.
Page 10 of 45
 Real and reactive power.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R5 of this standard.
NPCC Compliance Guidance Statement CGS-004 states that the 200 MVA Generating Plant capacity
threshold established by Requirement R4 also applies to Requirements R5 and R6
For TO, applies to elements connected to A10 busses only.
Auditor Notes:
R6 Supporting Evidence and Documentation
R6. Each Transmission Owner and Generator Owner shall provide Fault recording with the following
capabilities: [Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
6.1 Each Fault recorder record duration shall be a minimum of one (1) second.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
6.2 Each Fault recorder shall have a minimum recording rate of 16 samples per cycle
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
6.3 Each Fault recorder shall be set to trigger for at least the following:
6.3.1 Monitored phase overcurrents set at 1.5 pu or less of rated CT secondary current or Protective
Relay tripping for all Protection Groups.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
6.3.2 Neutral (residual) overcurrent set at 0.2 pu or less of rated CT secondary current.
Page 11 of 45
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
6.3.3 Monitored phase undervoltage set at 0.85 pu or greater.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
6.4 Document additional triggers and deviations from the settings in 6.3.2 and 6.3.3 when local
conditions dictate.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R6
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(TO) (GO) provided Fault recording with the following capabilities:
 Each Fault recorder record duration shall be a minimum of one (1) second.
 Each Fault recorder shall have a minimum recording rate of 16 samples per cycle.
 Each Fault recorder shall be set to trigger for at least the following:
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
o Monitored phase overcurrents set at 1.5 pu or less of rated CT secondary current or
Protective Relay tripping for all Protection Groups.
o Neutral (residual) overcurrent set at 0.2 pu or less of rated CT secondary current.
o Monitored phase undervoltage set at 0.85 pu or greater.
Documented additional triggers and deviations from the settings in 6.3.2 and 6.3.3 when local
conditions dictate.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R6 of this standard.
NPCC Compliance Guidance Statement CGS-004 states that the 200 MVA Generating Plant capacity
threshold established by Requirement R4 also applies to Requirements R5 and R6
For TO, applies to elements connected to A10 busses only.
Auditor Notes:
R7 Supporting Evidence and Documentation
R7. Each Reliability Coordinator shall establish its area’s requirements for Dynamic Disturbance
Recording (DDR) capability that: [Violation Risk Factor: Medium] [Time Horizon: Planning and
Operations Planning]
7.1 Provides a minimum of 1 DDR per 3,000 MW of peak Load.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
7.2 Records dynamic disturbance information with consideration of the following facilities/locations:
7.2.1 Major Load centers.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
7.2.2 Major Generation clusters.
Describe, in narrative form, how you meet compliance with this Requirement.
Page 13 of 45
Registered Entity Response (Required):
7.2.3 Major voltage sensitive areas.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
7.2.4 Major transmission interfaces.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
7.2.5 Major transmission junctions.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
7.2.6 Elements associated with Interconnection Reliability Operating Limits (IROLs).
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
7.2.7 Major EHV interconnections between operating areas.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Page 14 of 45
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R7
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(RC) established its area’s requirements for Dynamic Disturbance
Recording (DDR) capability that:
 Provides a minimum of 1 DDR per 3,000 MW of peak Load.
 Records dynamic disturbance information with consideration of the following facilities/locations:
o Major Load centers.
o Major Generation clusters.
o Major voltage sensitive areas.
o Major transmission interfaces.
o Major transmission junctions.
o Elements associated with Interconnection Reliability Operating Limits (IROLs).
o Major EHV interconnections between operating areas.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R7 of this standard.
Auditor Notes:
R8 Supporting Evidence and Documentation
R8. Each Reliability Coordinator shall specify that DDRs installed, after the approval of this standard,
function as continuous recorders. [Violation Risk Factor: Medium] [Time Horizon: Planning and
Operations Planning]
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Page 15 of 45
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R8
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
Specified that DDRs installed after approval date of standard, function as continuous recorders.
All DDRs installed after October 20, 2011 must function as continuous recorders.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, Compliance Clarification and
Q&A document defining the terminology and applicability of an entity’s assets to R8 of this standard.
“Approval date of this standard…” is October 20, 2011 for US entities and Canadian provinces
adhering to the FERC approval date. Otherwise “approval date” is November 4, 2010 the NERC
approval date.
Auditor Notes:
R9 Supporting Evidence and Documentation
R9. Each Reliability Coordinator shall specify that DDRs are installed with the following capabilities:
[Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
9.1 A minimum recording time of sixty (60) seconds per trigger event.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Page 16 of 45
9.2 A minimum data sample rate of 960 samples per second, and a minimum data storage rate for
RMS quantities of six (6) data points per second.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
9.3 Each DDR shall be set to trigger for at least one of the following (based on manufacturers’
equipment capabilities):
9.3.1 Rate of change of Frequency.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
9.3.2 Rate of change of Power.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
9.3.3 Delta Frequency (recommend 20 mHz change).
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
9.3.4 Oscillation of Frequency.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Page 17 of 45
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R9
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
Each Reliability Coordinator shall specify that DDRs are installed with the following capabilities:
 Each DDR installed after October 20, 2011 shall
o Function as a continuous recorder
o Have a minimum data sample rate of 960 samples per second, and a minimum data storage
rate for RMS quantities of six (6) data points per second.
 Each continuous DDR installed on, or prior to October 20, 2011, shall
o Have a minimum data sample rate of 960 samples per second, and a minimum data storage
rate for RMS quantities of six (6) data points per second.
 Each non-continuous DDR installed on, or prior to October 20, 2011, shall
o Have a minimum recording time of sixty (60) seconds per trigger event.
o Have a minimum data sample rate of 960 samples per second, and a minimum data storage
rate for RMS quantities of six (6) data points per second.
o Be set to trigger for at least one of the following (based on manufacturers’ equipment
capabilities):
 Rate of change of Frequency.
 Rate of change of Power.
 Delta Frequency (recommend 20 mHz change).
 Oscillation of Frequency.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, Compliance Clarification and
Q&A document defining the terminology and applicability of an entity’s assets to R9 of this standard.
Auditor Notes:
Page 18 of 45
R10 Supporting Evidence and Documentation
R10. Each Reliability Coordinator shall establish requirements such that the following quantities are
monitored or derived where DDRs are installed: [Violation Risk Factor: Medium] [Time Horizon:
Planning and Operations Planning]
10.1 Line currents for most lines such that normal line maintenance activities do not interfere with DDR
functionality.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
10.2 Bus voltages such that normal bus maintenance activities do not interfere with DDR functionality.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
10.3 As a minimum, one phase current per monitored Element and two phase-to-neutral voltages of
different Elements. One of the monitored voltages shall be of the same phase as the monitored current.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
10.4 Frequency.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
10.5 Real and reactive power.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Page 19 of 45
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R10
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
Each Reliability Coordinator shall establish requirements such that the following quantities are
monitored or derived where DDRs are installed:
 Line currents for most lines such that normal line maintenance activities do not interfere with
DDR functionality.
 Bus voltages such that normal bus maintenance activities do not interfere with DDR
functionality.
 As a minimum, one phase current per monitored Element and two phase-to-neutral voltages of
different Elements. One of the monitored voltages shall be of the same phase as the monitored
current.
 Frequency.
 Real and reactive power.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R10 of this standard.
Auditor Notes:
R11 Supporting Evidence and Documentation
R11. Each Reliability Coordinator shall document additional settings and deviations from the required
trigger settings described in R9 and the required list of monitored quantities as described in R10, and
report this to the Regional Entity (RE) upon request. [Violation Risk Factor: Lower] [Time Horizon:
Operations Planning]
Page 20 of 45
Question: Did the Reliability Coordinator document any additional settings or deviations from the
required trigger settings described in R9 or the required list of monitored quantities as described in
R10. If “Yes” provide narrative and evidence below.
Registered Entity Response (Required):
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R11
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
Documented additional settings and deviations from the required trigger settings described in R9 and
the required list of monitored quantities as described in R10.
 Trigger settings and their deviations are not applicable to DDRs installed after October 20,
2011.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R11 of this standard.
Auditor Notes:
Page 21 of 45
R12 Supporting Evidence and Documentation
R12. Each Reliability Coordinator shall specify its DDR requirements including the DDR setting
triggers
established in R9 to the Transmission Owners and Generator Owners. [Violation Risk Factor:
Medium] [Time Horizon: Planning and Operations Planning]
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R12
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(RC) specified its DDR requirements including the DDR setting triggers established in R9 to the
Transmission Owners and Generator Owners.
 Trigger settings and their deviations are not applicable to DDRs installed after October 20,
2011.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R12 of this standard.
Auditor Notes:
Page 22 of 45
R13 Supporting Evidence and Documentation
R13. Each Transmission Owner and Generator Owner that receives a request from the Reliability
Coordinator to install a DDR shall acquire and install the DDR in accordance with R12. Reliability
Coordinators, Transmission Owners, and Generator Owners shall mutually agree on an implementation
schedule. [Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
Question: Did the entity receive a request from the Reliability Coordinator to install a DDR in
accordance with R12? If “Yes” provide evidence for the request.
Registered Entity Response (Required):
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R13
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(TO)(GO) responded to the applicability Question with response “Yes” and provided evidence of
request?
If “Yes”, review documentation confirming that RC and entity agreed on an implementation
schedule.
If “Yes”, review documentation confirming that entity has taken action to acquire and install the
DDR in accordance with R12 and the agreed implementation schedule.
Note to Auditor:
Page 23 of 45
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R13 of this standard.
Auditor Notes:
R14 Supporting Evidence and Documentation
R14. Each Transmission Owner and Generator Owner shall establish a maintenance and testing program
for stand alone DME (equipment whose only purpose is disturbance monitoring) that includes:
[Violation Risk Factor: Medium] [Time Horizon: Operations Planning]
14.1 Maintenance and testing intervals and their basis.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
14.2 Summary of maintenance and testing procedures.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
14.3 Monthly verification of communication channels used for accessing records remotely (if the entity
relies on remote access and the channel is not monitored to a control center staffed around the clock, 24
hours a day, 7 days a week (24/7)).
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
14.4 Monthly verification of time synchronization (if the loss of time synchronization is not monitored
to a 24/7 control center).
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Page 24 of 45
14.5 Monthly verification of active analog quantities.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
14.6 Verification of DDR and DFR settings in the software every six (6) years.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
14.7 A requirement to return failed units to service within 90 days. If a DME device will be out of
service for greater than 90 days the owner shall keep a record of efforts aimed at restoring the DME to
service.
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R14
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(TO) (GO) established a maintenance and testing program for stand alone DME (equipment whose
only purpose is disturbance monitoring). Review evidence showing that program includes:
 Maintenance and testing intervals and their basis.
 Summary of maintenance and testing procedures.
 Monthly verification of communication channels used for accessing records remotely (if the
Page 25 of 45




entity relies on remote access and the channel is not monitored to a control center staffed
around the clock, 24 hours a day, 7 days a week (24/7)).
Monthly verification of time synchronization (if the loss of time synchronization is not
monitored to a 24/7 control center).
Monthly verification of active analog quantities. Verify that the quantities are being recorded,
not their accuracy.
Verification of DDR and DFR settings in the software every six (6) years.
A requirement to return failed units to service within 90 days.
o Review records of efforts aimed at restoring the DME to service if the DME device
was known or assumed to be out of service for greater than 90 days.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R14 of this standard.
Auditor Notes:
R15 Supporting Evidence and Documentation
R15. Each Reliability Coordinator, Transmission Owner and Generator Owner shall share data within 30
days upon request. Each Reliability Coordinator, Transmission Owner, and Generator Owner shall
provide recorded disturbance data from DMEs within 30 days of receipt of the request in each of the
following cases: [Violation Risk Factor: Lower] [Time Horizon: Operations]
15.1 NERC, Regional Entity, Reliability Coordinator.
Question: Did the Reliability Coordinator, Transmission Owner or Generator Owner receive a request
from NERC, the Regional Entity, or a Reliability Coordinator during the audit period to share DME
data?
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
15.2 Request from other Transmission Owners, Generator Owners within NPCC.
Question: Did the Transmission Owner, or Generator Owner receive a request from other Transmission
Owners, or Generator Owners during the audit period to share DME data?
Page 26 of 45
If yes, provide a list of the events and Registered Entities for which DME data was requested or
provided.
Registered Entity Response (Required):
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R15
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(RC) (TO) (GO) has shared recorded disturbance data from DMEs within 30 days of receipt of
request from the following:
 NERC, Regional Entity, Reliability Coordinator.
o An audit or spot check notification represents a request from the Regional Entity.
 other Transmission Owners, Generator Owners within NPCC.
o (TO, GO) responded to the applicability Question with response “Yes” and provided
list of events and GOs/TOs for which DME data was shared?
Page 27 of 45
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R15 of this standard.
Auditor Notes:
R16 Supporting Evidence and Documentation
R16. Each Reliability Coordinator, Transmission Owner and Generator Owner shall submit the data files
conforming to the following format requirements: [Violation Risk Factor: Lower] [Time Horizon:
Operations]
16.1 The data files shall be capable of being viewed, read, and analyzed with a generic COMTRADE
analysis tool as per the latest revision of IEEE Standard C37.111.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
16.2 Disturbance Data files shall be named in conformance with the latest revision of IEEE Standard
C37.232.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
16.3 Fault Recorder and DDR Files shall contain all monitored channels. SOE records shall contain
station name, date, time resolved to milliseconds, SOE point name, status.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Page 28 of 45
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R16
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(RC) (TO) (GO) has data files conforming to the following format requirements:
 The data files shall be capable of being viewed, read, and analyzed with a generic
COMTRADE analysis tool as per the latest revision of IEEE Standard C37.111.
o data provided in a commonly used format such as txt, csv, or xls is sufficient.
 Disturbance Data files shall be named in conformance with the latest revision of IEEE
Standard C37.232.
 Fault Recorder and DDR Files shall contain all monitored channels. SOE records shall
contain station name, date, time resolved to milliseconds, SOE point name, status.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R16 of this standard.
Auditor Notes:
R17 Supporting Evidence and Documentation
R17. Each Reliability Coordinator, Transmission Owner and Generator Owner shall maintain, record
and provide to the Regional Entity (RE), upon request, the following data on the DMEs installed to meet
this standard: [Violation Risk Factor: Lower] [Time Horizon: Operations]
17.1 Type of DME.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
17.2 Make and model of equipment.
Page 29 of 45
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
17.3 Installation location.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
17.4 Operational Status.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
17.5 Date last tested.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
17.6 Monitored Elements.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
17.7 All identified channels.
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
17.8 Monitored electrical quantities.
Page 30 of 45
Describe, in narrative form, how you meet compliance with this Requirement.
Registered Entity Response (Required):
Registered Entity Evidence (Required):
Provide the following for all evidence submitted (Insert additional rows if necessary):
File Name, File Extention, Document Title, Revision, Date, Page(s), Section(s), Section Title(s),
Description
Audit Team Evidence Reviewed (This section must be completed by the Compliance Enforcement
Authority):
Compliance Assessment Approach Specific to PRC-002-NPCC-01, R17
This section must be completed by the Compliance Enforcement Authority
Review the evidence to verify the Registered Entity has:
(RC) (TO) (GO) maintained, recorded and provided to the Regional Entity (RE), upon request, the
following data on the DMEs installed to meet this standard:
 Type of DME.
 Make and model of equipment.
 Installation location.
 Operational Status.
 Date last tested.
 Monitored Elements.
 All identified channels.
 Monitored electrical quantities.
Note to Auditor:
The NPCC Regional Standard has an Implementation Plan, Webinar, and Q&A document defining the
terminology and applicability of an entity’s assets to R17 of this standard.
Auditor Notes:
Page 31 of 45
Compliance Finding Summary
This section must be completed by the Compliance Enforcement Authority
Req.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
NF
PV
OEA NA
Statement
Page 32 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
A. Introduction
1.
Title:
Disturbance Monitoring
2.
Number:
PRC-002-NPCC-01
3.
Purpose:
Ensure that adequate disturbance data is available to facilitate Bulk
Electric System event analyses. All references to equipment and
facilities herein unless otherwise noted will be to Bulk Electric
System (BES) elements.
4.
Applicability:
4.1. Transmission Owner
4.2. Generator Owner
4.3. Reliability Coordinator
5.
(Proposed) Effective Date: To be established.
B. Requirements
R1. Each Transmission Owner and Generator Owner shall provide Sequence of
Event (SOE) recording capability by installing Sequence of Event recorders
or as part of another device, such as a Supervisory Control And Data
Acquisition (SCADA) Remote Terminal Unit (RTU), a generator plant
Digital (or Distributed) Control System (DCS) or part of Fault recording
equipment. This capability shall: [Violation Risk Factor: Medium] [Time
Horizon: Planning and Operations Planning]
1.1 Be provided at all substations and at locations where circuit
breaker operation affects continuity of service to radial Loads
greater than
300MW, or the operation of which drops 50MVA Nameplate Rating or
greater of Generation, or the operation of which creates a
Generation/Load island.
Be provided at generating units above 50MVA Nameplate Rating or
series of generating units utilizing a control scheme such that the loss
of 1 unit results in a loss of greater than 50MVA Nameplate Capacity,
and at Generating Plants above 300MVA Name Plate Capacity.
1.2 Monitor the following at each location listed in 1.1:
1.2.1 Transmission and Generator circuit breaker positions
1.2.2 Protective Relay tripping for all Protection Groups that
operate to trip circuit breakers identified in 1.2.1.
1.2.3 Teleprotection keying and receive
Adopted by NERC Board of Trustees: November 4, 2010
Page 33 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
R2. Each Transmission Owner shall provide Fault recording capability for the following Elements at facilities
where Fault recording equipment is required to be installed as per R3: [Violation Risk Factor: Medium]
[Time Horizon: Planning and Operations Planning]
2.1 All transmission lines.
2.2 Autotransformers or phase-shifters connected to busses.
2.3 Shunt capacitors, shunt reactors.
2.4 Individual generator line interconnections.
2.5 Dynamic VAR Devices.
2.6 HVDC terminals.
R3. Each Transmission Owner shall have Fault recording capability that determines the Current Zero
Time for loss of Bulk Electric System (BES) transmission Elements. [Violation Risk Factor: Medium]
[Time Horizon: Planning and Operations Planning]
R4. Each Generator Owner shall provide Fault recording capability for Generating Plants at and above 200
MVA Capacity and connected through a generator step up (GSU) transformer to a Bulk Electric
System Element unless Fault recording capability is already provided by the Transmission Owner.
[Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
R5. Each Transmission Owner and Generator Owner shall record for Faults, sufficient electrical quantities
for each monitored Element to determine the following: [Violation Risk Factor: Medium] [Time
Horizon: Planning and Operations Planning]
5.1 Three phase-to-neutral voltages. (Common bus-side voltages may be used for lines.)
5.2 Three phase currents and neutral currents.
5.3 Polarizing currents and voltages, if used.
5.4 Frequency.
5.5 Real and reactive power.
R6. Each Transmission Owner and Generator Owner shall provide Fault recording with the following
capabilities: [Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
6.1 Each Fault recorder record duration shall be a minimum of one (1) second.
6.2 Each Fault recorder shall have a minimum recording rate of 16 samples per
cycle
6.3 Each Fault recorder shall be set to trigger for at least the following:
6.3.1 Monitored phase overcurrents set at 1.5 pu or less of rated CT secondary current or
Protective Relay tripping for all Protection Groups.
6.3.2
Neutral (residual) overcurrent set at 0.2 pu or less of rated CT secondary current.
6.3.3 Monitored phase undervoltage set at 0.85 pu or greater.
6.4 Document additional triggers and deviations from the settings in 6.3.2 and 6.3.3 when local
conditions dictate.
R7. Each Reliability Coordinator shall establish its area’s requirements for Dynamic Disturbance
Recording (DDR) capability that: [Violation Risk Factor: Medium] [Time Horizon: Planning and
Operations Planning]
Adopted by NERC Board of Trustees: November 4, 2010
Page 34 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
7.1 Provides a minimum of 1 DDR per 3,000 MW of peak Load.
7.2 Records dynamic disturbance information with consideration of the following
facilities/locations:
7.2.1 Major Load centers.
7.2.2 Major Generation clusters.
7.2.3 Major voltage sensitive areas.
7.2.4 Major transmission interfaces.
7.2.5 Major transmission junctions.
7.2.6 Elements associated with Interconnection Reliability Operating Limits (IROLs).
7.2.7 Major EHV interconnections between operating areas.
R8. Each Reliability Coordinator shall specify that DDRs installed, after the approval of this standard,
function as continuous recorders. [Violation Risk Factor: Medium] [Time Horizon: Planning and
Operations Planning]
R9. Each Reliability Coordinator shall specify that DDRs are installed with the following capabilities:
[Violation Risk Factor: Medium] [Time Horizon: Planning and Operations Planning]
9.1 A minimum recording time of sixty (60) seconds per trigger event.
9.2 A minimum data sample rate of 960 samples per second, and a minimum data storage rate for
RMS quantities of six (6) data points per second.
9.3 Each DDR shall be set to trigger for at least one of the following (based on manufacturers’
equipment capabilities):
9.3.1 Rate of change of Frequency.
9.3.2 Rate of change of Power.
9.3.3 Delta Frequency (recommend 20 mHz change).
9.3.4 Oscillation of Frequency.
R10. Each Reliability Coordinator shall establish requirements such that the following quantities are
monitored or derived where DDRs are installed: [Violation Risk Factor: Medium] [Time Horizon:
Planning and Operations Planning]
10.1 Line currents for most lines such that normal line maintenance activities do not interfere with
DDR functionality.
10.2 Bus voltages such that normal bus maintenance activities do not interfere with DDR
functionality.
10.3 As a minimum, one phase current per monitored Element and two phase-to-neutral voltages of
different Elements. One of the monitored voltages shall be of the same phase as the monitored
current.
10.4 Frequency.
10.5 Real and reactive power.
R11. Each Reliability Coordinator shall document additional settings and deviations from the required
trigger settings described in R9 and the required list of monitored quantities as described in R10, and
Adopted by NERC Board of Trustees: November 4, 2010
Page 35 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
report this to the Regional Entity (RE) upon request. [Violation Risk Factor: Lower] [Time Horizon:
Operations Planning]
R12. Each Reliability Coordinator shall specify its DDR requirements including the DDR setting triggers
established in R9 to the Transmission Owners and Generator Owners. [Violation Risk Factor:
Medium] [Time Horizon: Planning and Operations Planning]
R13. Each Transmission Owner and Generator Owner that receives a request from the Reliability
Coordinator to install a DDR shall acquire and install the DDR in accordance with R12. Reliability
Coordinators, Transmission Owners, and Generator Owners shall mutually agree on an
implementation schedule. [Violation Risk Factor: Medium] [Time Horizon: Planning and
Operations Planning]
R14. Each Transmission Owner and Generator Owner shall establish a maintenance and testing program for
stand alone DME (equipment whose only purpose is disturbance monitoring) that includes: [Violation
Risk Factor: Medium] [Time Horizon: Operations Planning]
14.1 Maintenance and testing intervals and their basis.
14.2 Summary of maintenance and testing procedures.
14.3 Monthly verification of communication channels used for accessing records remotely (if the
entity relies on remote access and the channel is not monitored to a control center staffed around
the clock, 24 hours a day, 7 days a week (24/7)).
14.4 Monthly verification of time synchronization (if the loss of time synchronization is not
monitored to a 24/7 control center).
14.5 Monthly verification of active analog quantities.
14.6 Verification of DDR and DFR settings in the software every six (6) years.
14.7 A requirement to return failed units to service within 90 days. If a DME device will be out of
service for greater than 90 days the owner shall keep a record of efforts aimed at restoring the
DME to service.
R15. Each Reliability Coordinator, Transmission Owner and Generator Owner shall share data within 30
days upon request. Each Reliability Coordinator, Transmission Owner, and Generator Owner shall
provide recorded disturbance data from DMEs within 30 days of receipt of the request in each of the
following cases: [Violation Risk Factor: Lower] [Time Horizon: Operations]
15.1 NERC, Regional Entity, Reliability Coordinator.
15.2 Request from other Transmission Owners, Generator Owners within NPCC.
R16. Each Reliability Coordinator, Transmission Owner and Generator Owner shall submit the data files
conforming to the following format requirements: [Violation Risk Factor: Lower] [Time Horizon:
Operations]
16.1 The data files shall be capable of being viewed, read, and analyzed with a generic COMTRADE
analysis tool as per the latest revision of IEEE Standard C37.111.
16.2 Disturbance Data files shall be named in conformance with the latest revision of IEEE Standard
C37.232.
16.3 Fault Recorder and DDR Files shall contain all monitored channels. SOE records shall contain
station name, date, time resolved to milliseconds, SOE point name, status.
Adopted by NERC Board of Trustees: November 4, 2010
Page 36 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
R17. Each Reliability Coordinator, Transmission Owner and Generator Owner shall maintain, record and
provide to the Regional Entity (RE), upon request, the following data on the DMEs installed to meet
this standard: [Violation Risk Factor: Lower] [Time Horizon: Operations]
17.1 Type of DME.
17.2 Make and model of equipment.
17.3 Installation location.
17.4 Operational Status.
17.5 Date last tested.
17.6 Monitored Elements.
17.7 All identified channels.
17.8 Monitored electrical quantities.
C. Measures
M1. Each Transmission Owner and Generator Owner shall have, and provide upon request, evidence that it
provided Sequence of Event recording capability in accordance with 1.1 and 1.2. (R1)
M2. Each Transmission Owner shall have, and provide upon request, evidence that it provided Fault
recording capability in accordance with 2.1 to 2.6. (R2)
M3. Each Transmission Owner shall have, and provide upon request, evidence that it provided Fault
recording capability that determined the Current Zero Time for loss of Bulk Electric System (BES)
transmission Elements in accordance with R3.
M4. Each Generator Owner shall have, and provide upon request, evidence that it provided Fault recording
capability for its Generating Plants at and above 200 MVA Capacity in accordance with R4.
M5. Each Transmission Owner and Generator Owner shall have, and provide upon request, evidence that it
records for Faults, sufficient electrical quantities for each monitored Element to determine the
parameters listed in 5.1 to 5.5. (R5)
M6. Each Transmission Owner and Generator Owner shall have, and provide upon request, evidence that it
provided Fault recording capability in accordance with 6.1 to 6.4. (R6)
M7. Each Reliability Coordinator shall have, and provide upon request, evidence that it established its
area’s requirements for Dynamic Disturbance Recording (DDR) capability in accordance with 7.1 and
.2. (R7)
M8. Each Reliability Coordinator shall have, and provide upon request, evidence that DDRs installed after
the approval of this standard function as continuous recorders. (R8)
M9. Each Reliability Coordinator shall have, and provide upon request, evidence that it developed DDR
setting triggers to include the parameters listed in 9.1 to 9.3. (R9)
M10. Each Reliability Coordinator shall have, and provide upon request, evidence that DDRs monitor the
Elements listed in 10.1 through 10.5. (R10)
M11. Each Reliability Coordinator shall have, and provide upon request, evidence that it documented
additional settings and deviations from the required trigger settings described in R9 and the required
list of monitored quantities as described in R10. (R11)
Adopted by NERC Board of Trustees: November 4, 2010
Page 37 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
M12. Each Reliability Coordinator shall have, and provide upon request, evidence that it specified its DDR
requirements which included the DDR setting triggers established in R9 to the Transmission Owners
and Generator Owners in the Reliability Coordinator’s area. (R12)
M13. Each Transmission Owner and Generator Owner shall have, and provide upon request, evidence that
it acquired and installed the DDRs in accordance with the specifications contained in the Reliability
Coordinator’s request, and a mutually agreed upon implementation schedule. (R13)
M14. Each Transmission Owner and Generator Owner shall have, and provide upon request, evidence that it
has a maintenance and testing program for stand alone DME
(equipment whose only purpose is disturbance monitoring) that meets the requirements in 14.1
through 14.7. (R14)
M15. Each Reliability Coordinator, Transmission Owner and Generator Owner shall have, and provide
upon request, evidence that it provided recorded disturbance data from DMEs within 30 days of the
receipt of the request from the entities listed in 15.1 and 15.2. (R15)
M16. Each Reliability Coordinator, Transmission Owner and Generator Owner shall have, and provide
upon request, evidence that it submitted the data files in a format that meets the requirements in 16.1
through 16.3. (R16)
M17. Each Reliability Coordinator, Transmission Owner and Generator Owner shall have, and provide
upon request, evidence that it maintained a record of and provided to NPCC when requested, the data
on DMEs installed meeting the requirements 17.1 through 17.8. (R17)
D. Compliance
1.
Compliance Monitoring Process
1.1. Compliance Enforcement Authority
NPCC Compliance Committee
1.2. Compliance Monitoring Period and Reset Time Frame
Not Applicable
1.3. Data Retention
The Transmission Owner and Generator Owner shall keep evidences for three calendar years for
Measures 1, 5, 6, 13, 16 and 17.
The Transmission Owner shall keep evidence for three years for Measures 2 and 3.
The Generator Owner shall keep evidence for three years for Measure 4.
The Reliability Coordinator shall keep evidence for three years for Measures 7, 8, 9, 10, 11, 12,
16 and 17.
The Transmission Owner and Generator Owner shall keep evidences for twenty-four calendar
months for Measures 14 and 15.
The Reliability Coordinator shall keep evidence for twenty-four calendar months for Measure
15.
Adopted by NERC Board of Trustees: November 4, 2010
Page 38 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
If a Transmission Owner, Generator Owner or Reliability Coordinator is found non-compliant, it
shall keep information related to the non-compliance until found compliant.
The Compliance Enforcement Authority shall keep the last audit and all subsequent record.
1.4. Compliance Monitoring and Assessment Processes
-
Self-Certifications
Spot Checking
Compliance Audits
Self-Reporting
Compliance Violation Investigations
Complaints
1.5. Additional Compliance Information
None
2.
Violation Severity Levels
R#
Lower VSL
Moderate VSL
High VSL
Severe VSL
R1
The Transmission
Owner or
Generator Owner
provided the
Sequence of
Event recording
capability
meeting the bulk
of R1 but
missed…
Up to and
including 10%
of the total set,
which is the
product of the
total number of
locations in 1.1
times the total
number of
parameters in
1.2.
More than 10% and
up to and including
20% of the total set,
which is the product
of the total number
of locations in 1.1
times the total
number of
parameters in 1.2.
More than 20% and
up to and including
30% of the total set,
which is the product
of the total number
of locations in 1.1
times the total
number of
parameters in 1.2.
More than 30% of the
total set, which is the
product of the total
number of locations in
1.1 times the total
number of parameters in
1.2.
R2
The Transmission
Owner provided
the Fault
recording
capability
meeting the bulk
of R2 but
missed…
Up to and
including 10%
of the total set,
which is the
total number of
Elements at all
locations
required to be
installed as per
R3 that meet
the criteria
listed in 2.1
through 2.6.
More than 10% and
up to and including
20% of the total set,
which is the total
number of Elements
at all locations
required to be
installed as per R3
that meet the criteria
listed in 2.1 through
2.6.
More than 20% and
up to and including
30% of the total set,
which is the total
number of
Elements at all
locations required
to be installed as
per R3 that meet
the criteria listed in
2.1 through 2.6.
More than 30% of the
total set, which is the
total number of Elements
at all locations required
to be installed as per R3
that meet the criteria
listed in 2.1 through 2.6.
Adopted by NERC Board of Trustees: November 4, 2010
Page 39 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
R3
Not applicable. Not applicable.
Not applicable.
The Transmission
Adopted by NERC Board of Trustees: November 4, 2010
Fault recording capability
that determines the
Page 40 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
Owner failed to
provide…
R4
The Generator
Owner failed to
provide Fault
recording
capability at…
current zero time for loss
of transmission Elements.
Up to and
including 10%
of its
Generating
Plants at and
above 200
MVA Capacity
and connected
to a Bulk
Electric System
Element if
Fault recording
capability for
that portion of
the system is
inadequate.
R5
Up to and
The Transmission including 10%
Owner or
of the total set
Generator Owner of parameters,
failed to record
which is the
for the Faults… product of the
total number of
monitored
Elements and
the number of
parameters
listed in 5.1
through 5.5.
More than 10% and
up to and including
20% of its
Generating Plants at
and above 200 MVA
Capacity and
connected to a Bulk
Electric System
Element if Fault
recording capability
for that portion of
the system is
inadequate.
More than 20% and
up to 30% of its
Generating Plants at
and above 200 MVA
Capacity and
connected to a Bulk
Electric System
Element if Fault
recording capability
for that portion of
the system is
inadequate.
More than 30% of its
Generating Plants at and
above 200 MVA
Capacity and connected
to a Bulk Electric System
Element if Fault
recording capability for
that portion of the system
is inadequate.
More than 10% and
up to and including
20% of the total set
of parameters, which
is the product of the
total number of
monitored Elements
and the number of
parameters listed in
5.1 through 5.5.
More than 20% and
up to and including
30% of the total set
of parameters, which
is the product of the
total number of
monitored Elements
and the number of
parameters listed in
5.1 through 5.5.
More than 30% of the
total set of parameters,
which is the product of
the total number of
monitored Elements and
the number of parameters
listed in 5.1 through 5.5.
R6
The Transmission
Owner or
Generator Owner
failed …
To provide Fault
recording capability
for more than 10%
and up to and
including 20% of the
total set of
requirements, which
is the product of the
total number of
monitored Elements
and the total number
of capabilities
identified in 6.1
through 6.2.
OR
Failed to document
additional triggers or
To provide Fault
recording capability
for more than 20%
and up to and
including 30% of the
total set of
requirements, which
is the product of the
total number of
monitored Elements
and the total number
of 6.1 through 6.2.
OR
Failed to document
additional triggers or
deviations from the
settings stipulated in
To provide Fault
recording capability for
more than 30% of the
total set of requirements,
which is the product of
the total number of
monitored Elements and
the total number of
capabilities identified in
6.1 through 6.2.
OR
Failed to document
additional triggers or
deviations from the
settings stipulated in 6.3
through 6.4 for more than
ten (10) locations.
To provide
Fault recording
capability for
up to and
including 10%
of the total set
of
requirements,
which is the
product of the
total number of
monitored
Elements and
the total
number of
capabilities
identified in 6.1
Adopted by NERC Board of Trustees: November 4, 2010
Page 41 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
through 6.2.
deviations from the
6.3 through 6.4 for
OR
settings stipulated in more than five (5)
and up to and
Failed to
6.3 through 6.4 for
document
more than two (2)
including ten (10)
locations.
additional
and up to and
triggers or
including five (5)
deviations from locations.
the settings
stipulated in 6.3
through 6.4 for
up to 2
locations.
Up to and
More than 10% and More than 20% and
R7
including 10%
up to and including
The Reliability
up to and including
of the required
20% of the required 30% of the required
Coordinator
failed to establish DDR coverage DDR coverage for
DDR coverage for
for
its
area
as
its
area
as
per
7.1
its area’s
its area as per 7.1
per 7.1and 7.2. and 7.2.
requirements
and 7.2.
for…
R8
Not applicable. Not applicable.
Not applicable.
The Reliability
Coordinator failed
to specify
that DDRs
installed…
R9
Not applicable.
Not
The Reliability
applicable.
Coordinator failed
to specify that
DDRs are
installed
without…
R10
Not applicable. Not applicable.
The Reliability
Coordinator failed
to ensure that the
quantities listed in 10.1 through 10.5
are monitored or
derived…
R11
Up to two (2)
More than two (2)
The Reliability
facilities within and up to five (5)
Coordinator failed the Reliability
facilities within the
to document and Coordinator’s
Reliability
report to the
area that have a Coordinator’s area
Regional Entity
DDR.
that have a DDR.
upon request
additional settings and deviations
from the required
trigger settings
described in R9
Adopted by NERC Board of Trustees: November 4, 2010
More than 30% of the
required DDR coverage
for its area as per 7.1 and
7.2.
Function as continuous
recorders.
Not applicable.
The capabilities listed in
9.1 through 9.3.
Not applicable.
Where DDRs are
installed.
More than five (5)
and up to ten (10)
facilities within the
Reliability
Coordinator’s area
that have a DDR.
More than ten (10)
facilities within the
Reliability Coordinator’s
area that have a DDR.
Page 42 of 45
Standard PRC-002-NPCC-01— Disturbance Monitoring
and the required
list of monitored
quantities as
described in R10
for…
R12
Not applicable.
The Reliability
Coordinator faile d
to specify to the
Transmission
Owners and
Generator Owner s
its DDR
requirements
including the DDR setting
triggers
established in R9
but missed…
R13
Up to and
The Transmission including 10%
Owner or
of the
Generator Owner requirement set
failed to comply of the
with the
Reliability
Reliability
Coordinator’s
Coordinator’s
request to
request installing install DDRs,
the DDR in
with the
accordance with requirement set
R12 for…
being the total
number of
DDRs
requested times
the number of
setting triggers
specified for
each DDR.
R14
Established a
The Transmission maintenance
Owner or
and testing
Generator
program for
Owner…
stand alone
DME but
provided
incomplete data
for any one (1)
of 14.1 through
Not applicable.
Not applicable.
Established setting
triggers.
More than 10% and
up to 20% of the
requirement set
requested by the
Reliability
Coordinator for
installing DDRs,
with the requirement
set being the total
number of DDRs
requested times the
number of setting
triggers specified for
each DDR.
More than 20% and
up to 30% of the
requirement set
requested by the
Reliability
Coordinator for
installing DDRs,
with the requirement
set being the total
number of DDRs
requested times the
number of setting
triggers specified for
each DDR.
More than 30% of the
requirement set requested
by the Reliability
Coordinator and
installing DDRs, with the
requirement set being the
total number of DDRs
requested times the
number of setting triggers
specified for each DDR
OR
The Reliability
Coordinator,
Transmission Owners,
and Generator Owners
failed to mutually agree
on an implementation
schedule.
Established a
maintenance and
testing program for
stand alone DME
but provided
incomplete data for
more than one (1)
and up to and
including three (3)
of 14.1 through 14.7.
Established a
maintenance and
testing program for
stand alone DME
but provided
incomplete data for
more than three (3)
and up to and
including six (6) of
14.1 through 14.7.
Did not establish any
maintenance and testing
program for DME;
OR
The Transmission Owner
or Generator Owner
established a
maintenance and testing
program for DME but did
not provide any data that
Adopted by NERC Board of Trustees: November 4, 2010
Page 43 of 45
NERC Reliability Standard Audit Worksheet
14.7.
R15
The Reliability
Coordinator,
Transmission
Owner or
Generator Owner
provided recorded
disturbance data
from DMEs but
was late for…
R16
The Reliability
Coordinator,
Transmission
Owner or
Generator Owner
failed to submit…
R17
The Reliability
Coordinator,
Transmission
Owner or
Generator Owner
failed to maintain
or provide to
the Regional
Entity , upon
request…
meets all of 14.1 through
14.7.
Up to and
including
fifteen (15)
days in meeting
the requests of
an entity, or
entities in 15.1,
or 15.2.
More than fifteen
(15) days but less
than and including
thirty (30) days in
meeting the requests
of an entity, or
entities in 15.1 or
15.2.
More than 30 days
but less than and
including forty-five
(45) days in meeting
the requests of an
entity, or entities in
15.1 or 15.2.
More than forty-five (45)
days in meeting the
requests of an entity, or
entities in 15.1 or 15.2.
Up to and
including two
(2) data files in
a format that
meets the
applicable
format
requirements in
16.1 through
16.3.
Up to and
including two
(2) of the items
in 17.1 through
17.8.
More than two (2)
and up to and
including five (5)
data files in a format
that meets the
applicable format
requirements in 16.1
through 16.3.
More than five (5)
and up to and
including ten (10)
data files in a format
that meets the
applicable format
requirements in 16.1
through 16.3.
More than ten (10) data
files in a format that
meets the applicable
format requirements in
16.1 through 16.3.
More than two (2)
and up to and
including four (4) of
the items in 17.1 to
17.8.
More than four (4)
and up to and
including six (6) of
the items in 17.1
through 17.8.
More than six (6) of the
items in 17.1 through
17.8.
E. Associated Documents
Version History
Version
Date
Action
Change Tracking
NERC Reliability Standard Audit Worksheet
Compliance Enforcement Authority: ____NPCC_____
Registered Entity:_____________________________
NCR Number:_______________________________
Compliance Assessment Date:__________________
RSAW Version: RSAW_PRC-002-NPCC-01_2013_v1
Revision Date: March, 2014
Page 44 of 45
NERC Reliability Standard Audit Worksheet
1
November 4,
2010
Adopted by NERC Board of Trustees
1
October 20,
2011
FERC Order issued approving PRC002-NPCC-01 (FERC’s Order became
effective on October 20, 2011)
NERC Reliability Standard Audit Worksheet
Compliance Enforcement Authority: ____NPCC_____
Registered Entity:_____________________________
NCR Number:_______________________________
Compliance Assessment Date:__________________
RSAW Version: RSAW_PRC-002-NPCC-01_2013_v1
Revision Date: March, 2014
Page 45 of 45
New