RTO/ISO and Non-RTO/ISO Reporting Requirements

Performance Metric			Specific Metric(s)
A.	NERC Reliability Standards Compliance		1. References to which NERC standards are applicable 2. Number of violations self-reported and made public by NERC/FERC 3. Number of violations identified and made public as NERC audit findings 4. Total number of violations made public by NERC/FERC 5. Severity level of each violation made public by NERC/FERC 6. Compliance with operating reserve standards 7. Unserved energy (or load shedding) caused by violations. Additional detail will be provided on (1) number of events; (2) duration of the events; (3) whether the events occurred during on/off-peak hours; (4) additional information on equipment types affected and kV of lines affected; and (5) number of events (and severity and duration of events) resulting in load shedding based on the utilization of TPL-002 Footnote b criteria Utilities outside ISO and RTO regions should limit reporting to the same eight functional areas used by the ISOs and RTOs: 1. Balancing Authority 7. Transmission Planner 2. Interchange Authority 8. Transmission Service Provider 3. Planning Authority 4. Reliability Coordinator 5. Resource Planner 6. Transmission Operator
B.		Dispatch Reliability	1. Balancing Authority ACE Limit (BAAL) or CPS1 and CPS2 2. Energy Management System (EMS) availability
C.		Load Forecast Accuracy	Actual peak load as a percentage variance from forecasted peak load
D.		Wind Forecasting Accuracy	Actual wind availability compared to forecasted wind availability
E.		Unscheduled Flows	Difference between net actual interchange (actual measured power flow in real time) and the net scheduled interchange in megawatt hours Reported in FERC Form No. 714
F.		Transmission Outage Coordination	1. Percentage of ≥ 200 kV planned outages of 5 days or more for which ISO, RTO or utility notified customers at least 1 month prior to the outage commencement date 2. Percentage of ≥ 200kV outages cancelled by utility after being approved previously
G.		Long-Term Reliability Planning – Transmission	1. Number of facilities approved for construction due to reliability purposes 2. Percentage of approved construction projects on schedule and completed 3. Performance of planning process related to: a. Completion of reliability studies b. Completion of economic studies
H.		Long-Term Reliability Planning – Resources	1. Processing time for generation interconnection requests 2. Actual reserve margins compared with planned reserve margins
I.		Interconnection and Transmission Process Metrics	1. Number of requests 2. Number of studies completed 3. Average age of incomplete studies 4. Average time for completed studies 5. Total cost and types of studies completed (e.g., feasibility study, system impact study and facility study)
J.		Special Protection Systems (or Remedial Action Schemes)	1. Number of special protection systems 2. Percentage of special protection systems that responded as designed when activated Applicable pool of special protection systems should be based on how the reporting entity’s Regional Entity defines “special protection systems” 3. Number of unintended activations
K.		System Lambda	System Lambda (on marginal unit) Proposed System Lambda metric would not apply to utilities where the marginal price is typically set by hydro units System lambda data will be based on Form 714 information
L.		Resource Availability	1 - System forced outage rate as measured over 12 months
M.		Fuel Diversity	Fuel diversity in terms of energy, installed capacity and actual production