1. Standards Subject to Enforcement Currently Or Standards Subject to Future Enforcement TSS Meeting #169 May 6-8, 2015 By: Lesley Kayser-Sprouse

2. StandardTitle Effective Date CIP-014-1 (TO, TOP) Physical Security 10/1/2015 CIP-014-2Implementation Plan

4.  CIP-014-2 ◦ Final Ballot was approved on April 29 th ◦ 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.

5.  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 Systems  CIP-007-5 – System Security Management  CIP-008-5 – Incident Reporting & Response  CIP-009-5 – Recovery Plans for BES Cyber Systems  CIP-010-1 – Configuration Change Management & Vulnerability Assessments  CIP-011-1 – Information Protection

6.  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.CIP V5 Transition Program  Comment period until 6/15/15.

7.  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. StandardTitle Effective Date FAC-001-2 (TO, GO) Facility Interconnection Requirements 1/1/2016 FAC-002-2 (PC, TP, TO, DP, GO) Facility Interconnection Studies 1/1/2016

8.  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.

9. StandardTitle Effective Date MOD-025-2 (GO, TO*) Verification and Data Reporting of Generator Real and Reactive Power Capability and Synchronous Condenser Reactive Power Capability 7/1/2016 40% Verified 7/1/2017 60% Verified 7/1/2018 80% Verified 7/2/2019 100% Verified MOD-026-1 (GO, TP) Verification of Models and Data for Generator Excitation Control System or Plant Volt/Var Control Functions 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 MOD-027-1 (GO, TP) Verification of Models and Data for Turbine / Governor and Load Control or Active Power/Frequency Control Functions 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 MOD-031-1 (PC, TP, LSE) Demand & Energy Data SAR Comment Period until 5/19/15 MOD-032-1 (BA, GO, LSE, RP, TO, TP, TSP) Data for Power System Modeling and Analysis 7/1/2015 R1, 100% Verified 7/1/2016 R2 – R4, 100% Verified MOD-033-1 (PC, RC, TOP) Steady-State and Dynamic System Model Validation 7/1/2017 100% Verified

10.  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).

11.  Effective the 1 st day of the 1 st 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.)

12.  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).

13.  Effective the 1 st day of the 1 st 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.

14.  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.

15.  MOD-032-1 ◦ Consolidation and replacement of existing MOD-010-0, MOD-011-0, MOD- 012-0, MOD-013-1, MOD-014-0, and MOD-015-0.1 ◦ RSAW posted. RSAW ◦ 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.

16.  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.

17. StandardTitleEffective Date PRC-010-2 (PC, TP, UFLS Entity) Undervoltage Load Shedding Final Ballot approved PRC-019-1 (GO, TO) Coordination of Generating Unit or Plant Capabilities, Voltage Regulating Controls, and Protection 7/1/2016 40% Verified 7/1/2017 R1, 60% Verified 7/1/2018 R1, 80% Verified 7/1/2019 R1, 100% Verified PRC-019-2 (GO, TO) BOT Approved 2/15/15 PRC-024-1 (GO) Generator Frequency and Voltage Protective Relay Settings 7/1/2016 R1, R2, R3 & R4, 40% Verified 7/1/2017 R1, R2, R3, & R4, 60% Verified 7/1/2018 R1, R2, R3, & R4, 80% Verified 7/1/2019 R1, R2, R3, & R4, 100% Verified PRC-024-2 (GO) BOT Approved 2/15/15

18.  NERC posted webinar held on 2/3/15.  Initial Work ◦ 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  Phase 2 ◦ 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

19.  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.Inclusion I4 of the Bulk Electric System  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.

20. StandardTitle Effective Date TPL-001-4 (PC, TP) Transmission System Planning Performance Requirements 1/1/2015 R1, R7 1/1/2016 R2-R6, R8 Retire previous requirements TPL-007-1 (PC, TP, TO, GO) Transmission System Planned Performance for Geomagnetic Disturbance Events BOT Adopted: 12/17/20 14 Filed: 1/21/2015 Implementation Plan

21.  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.

22.  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 mid- March.CRT-3 ◦ 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.

23. ◦ 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.

24. ◦ 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.

25. ◦ 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.