1. Project WECC-0100 Standards Briefing WECC-0100 SDT April 7, 2016 W ESTERN E LECTRICITY C OORDINATING C OUNCIL

2. R1.1 Steady State Voltage Applicability – All applicable BES buses. Criterion: –At all applicable BES buses –95% to 105% of nominal for P0 event, –90 to 110% of nominal for P1-P7 events Discussion –Steady state voltage range for P0 event originates in ANSI C84.1 standard. No difference for 500 kV for simplification. –Wider range for P1-P7 events to allow for contingencies. –Discussed definition of nominal. TP/PC can define nominal in their individual criteria applicable to voltage limits in their system.

3. R1.2 Post-Contingency Voltage Deviation Applicability - At each applicable BES bus serving load. Concerned with BES busses either feeding load directly or busses feeding lower voltage system that serves load Criterion: –Post-Contingency steady-state voltage deviation at each applicable BES bus serving load shall not exceed 8% for P1 events Discussion –The 8% for P1 events is based on some entities indicating a state regulatory need, and some entities allowing 8% voltage deviation for shunt reactive power device switching after an outage. The main concern is voltage deviation in downward direction. –For P2-P7 events it was concluded it would be acceptable to not have voltage deviation criteria that is more stringent than allowing the steady state voltage range in requirement R1.1.

4. R1.3-1.6 Transient Voltage Performance Applicability - At each applicable BES bus serving load. Applies to P1-P7 events R1.3 – Voltage recovery to 80% of pre-contingency voltage within 20 seconds –Consideration for FIDVR events based on comments and experience. –Recognizes some load loss initiated during fault can’t be prevented. R1.4 – With a fault, following recovery above 80%,Vdip below 70% for 30~, below 80% for 2 seconds. –Guidance from IEEE 1668 Trial Use Recommended Practice for Voltage Sag and Short Interruption Testing for End Use Equipment. Type I and II tests seem reasonable, most transmission faults are non 3-phase. –Helps minimize load loss for subsequent swings not due to fault. –Also reviewed IEEE 1547 Interconnecting Distributed Resources. –White paper developed with Posting 3. R1.5 – Same performance as R1.4 for contingencies without a fault (event P2.1). R1.6 – Oscillations positively damped within 30 seconds.

5. R1.3 Example

6. R1.4 Example

8. Impacts to Other Systems WR2. – If an entity uses more stringent Criteria than WR1 that Criteria applies only to their own system unless otherwise agreed to by all Planning entities involved. WR3 – If an entity uses less stringent Criteria than WR1 shall allow others to have same impact to that part of system. These requirements carry over from the previous Criteria requirement WR2 which allowed systems to apply different requirements than Table W-1. Retains the philosophy of “allowable effects on other systems”.

9. WR4. Cascading and Uncontrolled Islanding Threshold Criteria to identify potential for Cascading or uncontrolled islanding. Criterion: –Post contingency analysis results in steady-state facility loading either exceeding 125% or the known trip setting. –Transient stability voltage recovery to above 80% longer than 20 seconds. –When unrestrained successive load loss or generation loss occurs. Discussion –Since Cascading or uncontrolled islanding would manifest itself differently in different parts of the system, a threshold criteria was developed where further investigation would be warranted. –For unrestrained successive load or generation loss, it is anticipated this would be an iterative study process as determined by the entity.

10. WR5 Voltage Stability Positive reactive power margin for the following: –For transfer paths 105% or 102.5% of path flow for P0-P1 or P2- P7 events respectively. –For load areas 105% or 102.5% of forecasted peak load for P0- P1 or P2-P7 events respectively. Discussions –Did not find good technical justification for changing existing real power margins used in previous Criteria. –Path or load area assumed to be voltage stable by at least demonstrating the margins specified. Discussion this is a criteria for transmission Planning over the Planning Horizon, not a methodology to find system voltage stability limits beyond what the system is planned for.

11. WR6 Make Criteria Available Entity that uses study criteria different from criteria in WR1 shall make their criteria available upon request within 30 days.

12. Frequency Dip Criteria Frequency dip criteria is not included in this Criteria. A frequency dip criteria was included in Table W1 which was retired. Drafting team did not find good technical justification for frequency dip impact to load. Under frequency concern is to protect generators. UFLS designed in coordinated fashion based on frequency excursion to prevent excessive gen loss, not based on frequency dip as defined by previous criteria. PRC-006 Automatic UF Load Shedding defines requirements for PC’s developing UFLS Programs, WECC Off Nominal Frequency Requirements. Generator frequency capability requirements defined in NERC PRC-024

13. Next Steps Ballot Pool open 3/21 - 4/8 Ballot open 4/12 - 4/28 Next Board meeting June 2016

14. Questions?