Standards Subject to
Enforcement Currently
Or
Standards Subject to
Future Enforcement
TSS Meeting #169
May 6-8, 2015
By: Lesley Kayser-Sprouse
Standard
CIP-014-1
(TO, TOP)
CIP-014-2
Title
Physical Security
Effective Effective Effective
Date
Date
Date
10/1/2015
Implementation Plan
Effective
Date

CIP-014-2
◦ Final Ballot was approved on April 29th
◦ Removes references to “widespread”
◦ Effective on the later of the first day following the Effective
Date of CIP-014-1 or the first day after CIP-014-2 is
approved by an applicable governmental authority.
◦ NERC posted a webinar held on 3/24/15.





CIP-002-5.1 – BES Cyber System Categorization
CIP-003-5 – Security Management Controls
CIP-004-5.1 – Personnel & Training
CIP-005-5 – Electronic Security Perimeters
CIP-006-5 – Physical Security of BES Cyber

CIP-007-5
CIP-008-5
CIP-009-5

CIP-010-1

CIP-011-1


Systems
– System Security Management
– Incident Reporting & Response
– Recovery Plans for BES Cyber
Systems
– Configuration Change Management
& Vulnerability Assessments
– Information Protection


NERC has posted a new group of FAQs CIP V5
Transition Program to the web page for industry
comment. NERC will review all comments provided
and incorporate changes before issuing a final
version of the May 1, 2015 FAQs.
Comment period until 6/15/15.
Standard

Title
Effective
Date
Facility
FAC-001-2
Interconnection
(TO, GO)
Requirements
1/1/2016
FAC-002-2 Facility
(PC, TP, TO, Interconnection
DP, GO)
Studies
1/1/2016
Effective
Date
Effective
Date
Effective
Date
FAC-001-2
◦ To avoid adverse impacts on the reliability of the BES, TOs and
applicable GOs must document and make Facility interconnection
requirements available so that entities seeking to interconnect will
have the necessary information.
◦ FAC-001-1 required the interconnection requirements to be
published.
◦ R3 drastically changed. No longer specifically required to address
breaker duty, surge protection, metering, telecommunication,
voltage, reactive power and power factor control, maintenance
coordination, etc.

FAC-002-2
◦ Each TP and each PC shall study the reliability impact of: (i)
interconnecting new generation, transmission, or electricity
end-user Facilities and (ii) materially modifying existing
interconnections of generation, transmission, or electricity
end-user Facilities.
◦ FAC-002-1 required that the GO, TO, DP, LSE seeking to
integrate coordinate with its TP and PA/PC.
Standard
MOD-025-2
(GO, TO*)
MOD-026-1
(GO, TP)
MOD-027-1
(GO, TP)
MOD-031-1
(PC, TP, LSE)
Title
Verification and Data
Reporting of Generator
Real and Reactive Power
Capability and
Synchronous Condenser
Reactive Power
Capability
Verification of Models
and Data for Generator
Excitation Control
System or Plant Volt/Var
Control Functions
Verification of Models
and Data for Turbine /
Governor and Load
Control or Active
Power/Frequency
Control Functions
Demand & Energy Data
Effective
Date
Effective
Date
Effective
Date
Effective Date
7/1/2016
40% Verified
7/1/2017
60%
Verified
7/1/2018
80%
Verified
7/2/2019
100% Verified
7/1/20189*
R2, 30%
Verified
(*WECC
Variance)
7/1/2020
R2, 50%
Verified
7/1/2021*
R2, 75%
Verified
7/1/202(4)2*
R2, 100%
Verified
7/1/20189*
R2, 30%
Verified
(*WECC
Variance)
7/1/2020
R2, 50%
Verified
7/1/2021*
R2, 75%
Verified
7/1/202(4)2*
R2, 100%
Verified
SAR
Comment
Period until
5/19/15
MOD-032-1
Data for Power System
(BA, GO, LSE, RP, TO, TP,
Modeling and Analysis
TSP)
7/1/2015
R1, 100%
Verified
Steady-State and
Dynamic System Model
Validation
7/1/2017
100%
Verified
MOD-033-1
(PC, RC, TOP)
7/1/2016
R2 – R4,
100%
Verified

MOD-025-2
◦ GO must provide its TP with verification of its real and
reactive power capability.
◦ TO must provide its TP with verification of it reactive power
capability.

MOD-026-1
◦ GO should have already received instructions on how to
obtain excitation models.
◦ GO should be working toward getting those models. 30%
verified in 2018 (2019 with WECC Variance).


Effective the 1st day of the 1st calendar quarter after NERC BOT
approval.
Must have recorded response from either a staged test or a
measured system response.
◦ Staged test must include terminal voltage, real power, reactive power, field
voltage and current of generator or exciter, have 30+ samples per second.
◦ Measured system must compare actual real and reactive power to the
modeled. Real and reactive power measurements must both either be at
point of interconnection or generator terminals. Must have 30+ samples
per second.


GO must provide the revised models or its plan to perform model
verification within 180 days of making changes to excitation or
volt/var control function.
GO must provide a list of items to the TP when validation has not
been previously performed. (No timeframe given for Posting 4 even
though a response to a comment for Posting 3 says 5 years from the
effective date of this variance.)

MOD-027-1
 GO should have already received from its TP instructions
for obtaining turbine/governor and load models.
 GO should be working to get the models. 30% verified in
2018 (2019 with WECC Variance).


Effective the 1st day of the 1st calendar quarter after
NERC BOT approval.
Must have recorded response from either a
measured or staged system response.
◦ Measured system must compare actual real power output to
the modeled output. Measured power output and frequency
must both either be at point of interconnection or
generator terminals. Must have 10+ samples per second.
◦ Staged test should have 10+ samples per second.

GO shall provide revised model and validation data
to its TP within 5 years of the effective date of this
variance if validation has not been previously
performed.


SAR Posted
Ensuring that planners and operators have access
to complete and accurate load forecasts – as well
as the supporting methods and assumptions used
to develop these forecasts – will enhance the
reliability of the BPS. Collection of actual demand
and demand-side management performance
during the prior year will allow for comparison to
prior forecasts and further contribute to enhanced
accuracy of load forecasting practices.

MOD-032-1
◦ Consolidation and replacement of existing MOD-010-0, MOD-011-0, MOD012-0, MOD-013-1, MOD-014-0, and MOD-015-0.1
◦ RSAW posted.
◦ Each PC and each of its TP shall jointly develop steady-state,
dynamics, and short circuit modeling data requirements and
reporting procedures for the PC’s planning area that include:
 1.1. The data listed in Attachment 1. (Page 12)
 1.2. Specifications of the following items consistent with procedures for
building the Interconnection-wide case(s):




1.2.1. Data format;
1.2.2. Level of detail to which equipment shall be modeled;
1.2.3. Case types or scenarios to be modeled; and
1.2.4. A schedule for submission of data at least once every 13 calendar
months.
 1.3. Specifications for distribution or posting of the data requirements
and reporting procedures so that they are available to those entities
responsible for providing the data.

MOD-033-1
◦ Exists in conjunction with MOD-032-1, both of which are
related to system-level modeling and validation.
◦ Requires each PC to implement a documented process to
perform model validation within its planning area.
◦ Requires each RC and TO to provide actual (state estimator
or other real-time data) system behavior to the PC
performing validation.
Standard
Title
PRC-010-2
(PC, TP,
Undervoltage Load
UFLS
Shedding
Entity)
PRC-019-1 Coordination of
(GO, TO) Generating Unit or
Plant Capabilities,
Voltage Regulating
Controls, and
PRC-019-2
Protection
(GO, TO)
PRC-024-1
(GO)
Generator
Frequency and
Voltage Protective
Relay Settings
PRC-024-2
(GO)
Effective Date
Effective Date
Effective Date
Effective Date
7/1/2018
R1, 80%
Verified
7/1/2019
R1, 100%
Verified
Final
Ballot
approved
7/1/2016 7/1/2017
40%
R1, 60%
Verified
Verified
BOT
Approved
2/15/15
7/1/2016 7/1/2017
7/1/2018
7/1/2019
R1, R2, R3 R1, R2,
R1, R2, R3, R1, R2, R3,
& R4,
R3, & R4,
& R4,
& R4, 100%
40%
60%
80% Verified
Verified
Verified
Verified
BOT
Approved
2/15/15

NERC posted webinar held on 2/3/15.
Initial Work

Phase 2

◦ Addressed Undervoltage Load Shedding Programs (“UVLS
Program”)
◦ Created PRC‐010‐1
◦ Retired PRC‐020‐1, PRC‐021‐1, and PRC‐022‐1
◦ Held off addressing UVLS equipment Misoperations due to
concurrent work on PRC‐004‐3 by another team
◦ Completes the work anticipated by the UVLS and
Misoperation SDTs
◦ Inserts Applicability in PRC‐004 for UVLS that trips BES
Elements
◦ Clarifies that PRC‐010 includes UVLS equipment
◦ Concerning Misoperation of UVLS equipment due to the
retirement of PRC‐022‐1

PRC-019-2
◦ Facilities
 For the purpose of this standard, the term, “applicable Facility” shall mean
any one of the following:
 4.2.1 Individual generating unit greater than 20 MVA (gross nameplate
rating) directly connected to the Bulk Electric System.
 4.2.2 Individual synchronous condenser greater than 20 MVA (gross
nameplate rating) directly connected to the Bulk Electric System.
 4.2.3 Generating plant/ Facility consisting of one or more units that are
connected to the Bulk Electric System at a common bus with total generation
greater than 75 MVA (gross aggregate nameplate rating).
 (ADDED) 4.2.3.1 This includes individual generating units of the dispersed
power producing resources identified through Inclusion I4 of the Bulk Electric
System definition where voltage regulating control for the facility is performed
solely at the individual generating unit of the dispersed power producing
resources.
 4.2.4 Any generator, regardless of size, that is a blackstart unit material to
and designated as part of a Transmission Operator’s restoration plan.

PRC-024-2 – Same addition as PRC-019-2.
Standard
Title
Effective
Date
Effective
Date
Transmission
TPL-001-4
System Planning
(PC, TP)
Performance
Requirements
1/1/2016
R2-R6, R8
1/1/2015
Retire
R1, R7
previous
requirements
Transmission
System Planned
TPL-007-1
Performance for
(PC, TP,
Geomagnetic
TO, GO)
Disturbance
Events
BOT
Adopted:
12/17/20
14
Filed:
1/21/2015
Effective Date
Implementation
Plan
Effective
Date

TPL-001-4
◦ Px events
◦ Short circuit analysis
◦ If situations arise that are beyond the control of the TP or PC
that prevent the implementation of a Corrective Action Plan in
the required timeframe, then the TP or PC is permitted to
utilize Non-Consequential Load Loss and curtailment of Firm
Transmission Service to correct the situation that would
normally not be permitted in Table 1, provided that the TP or
PC documents that they are taking actions to resolve the
situation.
◦ Each PC and TP shall distribute its Planning Assessment results
to adjacent Planning Coordinators and adjacent Transmission
Planners within 90 calendar days of completing its Planning
Assessment.


Requirements WR1, WR2, WR4 and WR5 of original
CRT/RBP 2.1 retired.
Version 2 of CRT-3 addressing the original WR3,
Table W-1 and TPL-001-4 Requirements R5 & R6
and a response to comments was posted midMarch.
◦ WR1:
 Steady-State voltages at BES buses must be 95-105% of nominal
for P0 events, 90-105% for P1-P7 events
 Post contingency voltages shall not exceed 8% for P1.
 Transient Stability voltage shall recover to 80% of pre voltage
within 10 seconds for P1-P7.
 Subsequent voltage dips at BES load buses shall not remain
below 60% for more than 1s or below 70% for more than 5s for
P1-P7.
 Oscillations shall show positive damping with 30s.
◦ WR2:
 If TP and PC use more stringent criteria then it only applies to
its own system.
◦ WR3:
 If TP and PC use less stringent criteria then other TPs and PCs
can have same impact on that system.
◦ WR4:
 Indicators for identifying the potential for cascading or
uncontrolled islanding that need further investigation:
 Post contingency loading in excess of facility trip setting
and/or (TBD)
 Post contingency loading of 125% of highest facility rating.
◦ WR4 (cont):
 Transient stability voltage response outside criteria.
 Successive load or generation loss occurs outside of the area
being studied.
◦ WR5:
 TP and PC shall identify voltage stability by maintaining positive
reactive power margin at the real power flow defined by:
 All P0-P1 events shall demonstrate:
 positive reactive power margin at a minimum of 105% of
transfer path flow and forecasted peak load.
 All P2-P7 events shall demonstrate:
 Positive reactive power margin at a minimum of 102.5% of
transfer path flow and forecasted peak load.
◦ WR6:
 TP and PC must make criteria available upon request if
using study criteria different from WR1.



Anticipating one more revision.
Pending white paper to address simulations needed
to justify and refine the proposed criteria.
Next meeting is 5/18/15.