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Federal Register / Vol. 86, No. 162 / Wednesday, August 25, 2021 / Notices
45980, in the first column after the words Kimberly D. Bose, Secretary insert the following additional text:

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Post-Technical Conference Questions for Comment 1. Multiple panelists at the technical conference suggested that utilities and other industry participants should engage in an assessment of climate change risks to their systems.1 Should public utilities be required to engage in either a one-time assessment or periodic assessments of climate change risks to their assets and/or on how their system is expected to perform under expected climate change driven scenarios? If so, should such requirements be incorporated into jurisdictional local transmission planning and/or regional transmission planning/cost allocation process tariff provisions? Similarly, should such requirements be incorporated into FERC-jurisdictional resource adequacy tariff provisions?
2. Several panelists at the technical conference suggested that greater use of probabilistic approaches could provide a more robust approach to accounting for extreme weather.2 Would incorporating probabilistic methods into local transmission planning and/or regional transmission planning/cost allocation processes allow public utility transmission providers to more effectively assess low probability/high impact events and common mode failures? 3 If so, should such practices be incorporated into public utility transmission providers local transmission planning and/or regional transmission planning/cost allocation processes? What, if any, jurisdictional tariff changes would be necessary to incorporate these practices into existing transmission planning and cost allocation processes? Similarly, should such practices be incorporated into any resource adequacy assessments carried out under FERC-jurisdictional tariff provisions?
3. At the technical conference, panelists noted the importance of coordinating transfers across the seams between Regional Transmission 1 See June 1 Tr. at 14 Adam Smith; 17 Jessica Hogle; 55, 83 Romany Webb; 79 Derek Stenclik.
2 See June 1 Tr. at 3637, 81 Lisa Barton; 53, 69
70 Judy Chang; 79, 92 Derek Stenclik; 83
Romany Webb; 119 Richard Tabors; 129 Neil Millar.
3 As described in the March 15, 2021
Supplemental Notice of Technical Conference Inviting Comments in this proceeding, common mode failures occur where, due to climate change or an extreme weather event, a large number of facilities critical to electric reliability e.g., generation resources, transmission lines, substations, and natural gas pipelines experience outages or significant operational limitations, either simultaneously or in close succession.

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Organizations/Independent System Operators RTOs/ISOs and non-RTO/
ISO areas to both reduce costs and improve the resilience of the transmission grid during extreme weather events.4 How do RTO/ISO and non-RTO/ISO transmission providers manage congestion at system seams?
What are the benefits and drawbacks of the current management regime, from the perspectives of cost, resource participation, and ability to maximize reliability and other benefits of transmission service? Can more costeffective congestion management at the border between RTOs/ISOs and neighboring non-RTO/ISO transmission providers be facilitated through new pro forma Open Access Transmission Tariff OATT provisions? If so, how could the pro forma OATT be modified to achieve this enhanced coordination? For example, could existing pro forma OATT section 33.2 Transmission Constraints, which permits a transmission provider to use redispatch to maintain reliability during transmission constraints, be modified to enhance coordination with a neighboring RTO/ISO during such redispatch? Are there any other potential modifications to the pro forma OATT that might facilitate cost-effective congestion management at the border between RTOs/ISOs and neighboring non-RTO/ISO transmission providers? If so, please describe them in as much detail as possible. If such modifications were made to the pro forma OATT, could they also help improve coordination between RTOs/ISOs and non-jurisdictional entities through their inclusion in the reciprocity tariffs that are voluntarily filed by some nonjurisdictional entities? What challenges would any such modifications need to address?
4. RTOs/ISOs currently have differing levels of authority to approve or recall outages.5 Can generation and transmission outage scheduling practices be improved? For example, should RTOs/ISOs have greater authority to deny generation and transmission outage requests, such as having the ability to deny such a request based on estimated economic impact, as ISO New England currently has?
Similarly, should transmission owners be given an incentive to schedule transmission outages more efficiently by making transmission owners responsible for uplift they cause from 4 See June 2 Tr. at 64, 6667 Renuka Chatterjee;
68 Amanda Frazier; 153 Dan Scripps; 66 David Patton.
5 See June 2 Tr. at 2123, 32 Wesley Yeomans;
2324 Renuka Chatterjee; 3031, 7475 David Patton.

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outages, as the New York Independent System Operator currently does? Would such changes help system operators better prepare for or respond to extreme weather events?
5. Transmission topology optimization also sometimes known as transmission switching involves dynamically modifying transmission topology as a component of determining optimal day-ahead and real-time energy market solutions.6 Should RTOs/ISOs be required to incorporate transmission switching or transmission topology optimization in their day-ahead and real-time energy markets? Could the adoption of such optimization approaches both reduce costs and improve the resilience of the transmission grid?
6. Panelists at the technical conference suggested that current requirements for system performance under extreme weather scenarios may need to evolve.7 Should the transmission planning requirements established under North American Electric Reliability Corporation NERC
reliability standard TPL0014/5 be modified to better assess and mitigate the risk of extreme weather events and associated common mode failures?
Should any additional changes be considered to the NERC Reliability Standards to address the risk of extreme weather events?
7. Multiple panelists at the conference emphasized the need to establish a requirement for interregional transmission planning and improve existing interregional cost allocation methods to prepare for extreme weather events.8 How can the existing requirement to have an interregional transmission coordination not planning and cost allocation process be modified to better account for the benefits that interregional transmission facilities provide during extreme weather events? Would defining a set of uniform transmission benefit metrics that can be used across regions in the interregional transmission coordination and cost allocation processes help interregional transmission projects come to fruition? If so, please propose such metrics in as much detail as possible.
8. Would having a target level of interregional transfer capacity help facilitate more effective development of interregional transmission projects?
6 See June 2 Tr. at 7Amanda Frazier, 55 Renuka Chatterjee, 5557 Mads Almassalkhi, 5859
David Patton, 6061 Robin Broder-Hytowitz, 61
62 Anne Hoskins, 9496 Charles Long, 9798
Daniel Brooks, 136 Letha Tawney.
7 June 1 Tr. at 13840 Mark Lauby.
8 June 2 Tr. at 6466 Renuka Chatterjee, 147
Patricia Hoffman, 153 Dan Scripps.

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