MISO PAC April 22 Meeting Summary
The MISO Planning Advisory Committee meeting on April 22, 2026 focused on several major transmission-planning and interconnection-related matters, including Long Range Transmission Planning variance determinations, elimination of Planning Participation Credit, treatment of co-located load and generation through a Zero-Injection Generator Interconnection Agreement framework, Large Load reliability requirements, and MISO’s ongoing FERC Order 1920 compliance efforts. The agenda also included routine administrative items, status updates from planning-related stakeholder groups, and a liaison report covering current MISO planning activities.
(1.) Planning and Stakeholder Process Updates
The meeting began with administrative items including review of the agenda, prior meeting minutes, action items, and the PAC Management Plan. MISO also provided status updates from the Planning Subcommittee and Steering Committee. The Interconnection Process Working Group did not provide a report.
The Planning Subcommittee update primarily focused on the ongoing MTEP26 process, cost-estimation updates, and planning-study activities. MISO indicated that steady-state modeling work is progressing and that analysis activities are expected to increase as MTEP26 advances. MISO also discussed updates to its Cost Estimation Guide, including escalation adjustments and changes intended to better reflect current market conditions for transmission equipment and construction costs.
The Steering Committee update focused on stakeholder-process coordination and upcoming engagement opportunities. MISO highlighted several continuing workstreams, including the Large Load Working Group, FERC Order 1920 implementation, Expedited Project Review-related discussions, and other planning-process initiatives. Overall, these updates showed that MISO is managing several parallel planning reforms, many of which are linked to the rapid growth of large loads, data centers, co-located resources, and long-term regional transmission needs.
(2.) LRTP Variance Analysis Outcome Determinations
MISO presented post-only outcome determinations for two Long Range Transmission Planning projects.
For LRTP Tranche 1 Project 16, involving the Morrison Ditch – Reynolds – Burr Oak – Leesburg – Hiple transmission project, MISO reviewed a cost variance that exceeded the Tariff threshold requiring further analysis. The project’s estimated cost had increased significantly from the original approved estimate. MISO identified several cost drivers, including construction matting, technical services, contingency, right-of-way acquisition, and permitting costs. Rather than canceling or reassigning the project, MISO and NIPSCO agreed to a mitigation plan that resets the project’s baseline cost estimate and increases future reporting and oversight. This approach allows the project to continue while improving cost-control visibility.
For LRTP Tranche 2.1 Project 28, MISO reviewed certain substation facilities associated with the Wisconsin Southeast 345 kV project. The issue was driven by an accelerated in-service need associated with anticipated data-center load in Wisconsin. MISO determined that the required in-service date could not be reliably met under the original competitive transmission project structure. As a result, MISO determined that three substation facilities should be reassigned to American Transmission Company, while the remaining competitive project scope would continue with the originally selected developer. This determination reflects MISO’s willingness to modify project execution responsibility when system needs or schedule requirements change materially.
(3.) Elimination of Planning Participation Credit
MISO introduced a new issue, PAC-2026-1, proposing to eliminate Planning Participation Credit from the Competitive Transmission Process.
Under the current process, entities may receive credit for submitting transmission-solution ideas during planning studies, and that credit may be considered later in competitive transmission project evaluations. MISO stated that the credit has not served as a meaningful differentiator in competitive evaluations and has created additional administrative burden. The proposed change would eliminate the tracking and use of Planning Participation Credit while still allowing stakeholders to submit planning ideas during the study process.
The proposal would require revisions to Tariff Attachment FF and applicable Business Practices Manuals. MISO is targeting a FERC filing and acceptance process that would allow the change to be implemented by the end of 2026.
(4.) Zero-Injection Generator Interconnection Agreement Framework
A significant portion of the meeting focused on MISO’s proposed Zero-Injection Generator Interconnection Agreement framework under PAC-2024-4.
The proposal is intended to address generation that is directly or contractually associated with a specific load and is not intended to inject energy into the broader MISO transmission system. This issue is becoming increasingly important as large loads, including data centers and industrial facilities, explore co-located or behind-the-meter generation arrangements.
MISO’s proposed framework would create a limited interconnection pathway for resources serving associated load under strict conditions. The resource would be required to operate in a manner that does not materially impact the transmission system or create a need for network upgrades. MISO also emphasized that a Zero-Injection GIA would not provide full injection rights. If a resource seeks Energy Resource Interconnection Service or Network Resource Interconnection Service it would still need to proceed through the standard generator interconnection process.
Key elements of the proposal include separate metering and modeling of the generator and associated load, continued treatment of the load as gross Network Load, and the requirement that Network Integration Transmission Service obligations remain in place. MISO also proposed limits on the size of the zero-injection resource relative to the associated load and identified a study process to evaluate whether the arrangement can operate without adverse reliability impacts.
Stakeholders raised concerns regarding cost-shifting, modeling assumptions, treatment of multiple resources serving one load, and whether zero-injection arrangements could later create reliability or transmission-upgrade obligations. MISO clarified that the proposal is not intended to change cost allocation or allow resources to avoid the normal interconnection process where injection rights are required.
(5.) Large Load Definition and Reliability Requirements
MISO also continued discussion of its proposed Large Load definition and related interconnection reliability requirements under PAC-2024-1.
The proposed definition is intended to establish a consistent framework for identifying large commercial and industrial loads that may require additional reliability review. MISO retained a 50 MW threshold for new Large Loads and proposed that expansions of existing loads could also qualify if they increase load by a defined amount above a baseline value. The framework is especially relevant for data centers and other large industrial developments that can materially affect local and regional transmission-system performance.
MISO clarified that classification as a Large Load does not automatically mean that every reliability requirement applies. Instead, Large Loads would be screened based on their characteristics and system impacts. This distinction is important because it allows MISO to apply additional requirements where reliability risk exists, while avoiding unnecessary requirements for loads that do not materially affect the system.
MISO also discussed transition language for projects already under development. Loads that are not yet in service by the effective date may be subject to the new requirements depending on their size, development status, and whether they have already been reflected in planning processes such as MTEP or Expedited Project Review.
(6.) FERC Order 1920 Update
MISO provided an update on its compliance work for FERC Order 1920 and Order 1920-A, which require reforms to long-term regional transmission planning and cost allocation. MISO indicated that it remains on track for a regional compliance filing in June 2026.
Stakeholder feedback has focused on benefits measurement, project evaluation and selection, right-sizing criteria, grid-enhancing technologies, CEII treatment, and implementation timelines. MISO noted that some items will be addressed directly in Tariff language, while other implementation details will be developed later through Business Practices Manual updates. MISO expects additional stakeholder engagement to continue after the compliance filing as regional implementation details are refined.
(7.) Key Takeaways
The April 22 PAC meeting showed that MISO is actively reshaping its planning and interconnection processes to respond to rapid load growth, co-located generation, rising transmission costs, and federal planning reforms. The most important themes were:
- MISO is increasing attention on large-load reliability impacts, particularly for data centers and industrial developments.
- The proposed Zero-Injection GIA framework is intended to support co-located generation while preserving reliability, metering transparency, and gross-load transmission-service obligations.
- LRTP variance analysis is becoming an important tool for managing cost escalation, project scope changes, and schedule risks.
- MISO is simplifying the Competitive Transmission Process by proposing to remove Planning Participation Credit.
- FERC Order 1920 compliance remains a major 2026 priority, with detailed implementation work expected to continue after the June filing.
Overall, the meeting reflected MISO’s broader effort to modernize its planning framework while maintaining reliability, cost transparency, and stakeholder participation as large-load development accelerates across the footprint.
Contact ZEG to assess how MISO’s evolving planning frameworks, large load requirements, and interconnection pathways may impact your project development and grid strategy.
