A Coordinated Electric System Interconnection Review—the utility’s deep-dive on technical and cost impacts of your project.

1. What is the primary goal of the 2025 ITP?
To develop a regional transmission plan that ensures reliability, affordability, and public policy compliance.
2. Who oversees the 2025 ITP?
SPP’s Economic Studies Working Group (ESWG), Transmission Working Group (TWG), and the Market Operations and Policy Committee (MOPC).
3. What are the planning years used?
2025 (Year 1), 2026 (Year 2), 2029 (Year 5), and 2034 (Year 10).
4. What are Futures 1 and 2?
Scenarios that reflect moderate (F1) and high-growth/emerging tech (F2) demand conditions.
5. What are the key resiliency scenarios?
Summer stress, winter outages, and EV-driven load spikes.
6. What is the Planning Reserve Margin (PRM)?
16% for summer, 27% (2029), and 35% (2034) for winter.
7. How are resources accredited?
Using Effective Load Carrying Capability (ELCC) with Tier 1 and Tier 2 resource classifications.
8. How does SPP define “must-run” units?
Hydro, nuclear, landfill gas, and co-gen units unless exceptions apply.
9. What role do curtailment prices play?
They reflect tax credits and impact dispatch in economic models.
10. What are hurdle rates?
They simulate interregional transaction costs and are adjusted based on vendor data.
11. How is resiliency need assessed?
Using LMP impact, transferability between zones, and potential for load shedding.
12. What is the Southeastern SPP target area?
A region flagged by AEP for low voltages, high congestion, and stability issues.
13. How is generation assigned in modeling?
Based on policy, utility requests, and resource planning templates.
14. What are generator prototypes?
Standardized generation models using EIA data for economic simulations.
15. How is storage modeled?
Storage capacities increase in later years; e.g., 19.2 GW in Year 10 for Future 2.
16. What is the role of Distributed Generation?
Included based on utility submissions but excluded from detailed control modeling.
17. How are extreme events simulated?
Through monthly model alterations (e.g., January and July) to reflect stress.
18. How is LMP used for planning?
To identify constrained, high-value generators during peak demand.
19. How does SPP handle load additions?
Through forecast validation and inclusion in Future 2 spot load scenarios.
20. What are MEM and RMEM?
Market Economic Models with and without resiliency overlays.
21. How is project value measured?
By a scoring matrix including APC benefits, congestion relief, and viability.
22. What is the ITP project timeline?
Runs from July 2023 to October 2025.
23. How are voltage stability and sensitivities handled?
Through final assessments using consolidated portfolios and TWG input.
24. How does SPP address evolving assumptions?
By formally revising the scope under stakeholder protocols.
25. How can stakeholders participate?
Through working group engagements, model reviews, and the solution vetting process.

In 1995, Sandip (Sonny) R. Patel earned his Electrical Engineering degree from the University of Illinois, specializing in Electrical Engineering . But degrees don’t build legacies—action does. For three decades, he’s been shaping the future of engineering, not just as a licensed Professional Engineer across multiple states (Florida, California, New York, West Virginia, and Minnesota), but as a doer. A builder. A leader. Not just an engineer. A Licensed Electrical Contractor in Florida with an Unlimited EC license. Not just an executive. The founder and CEO of KEENTEL LLC—where expertise meets execution. Three decades. Multiple states. Endless impact.

SPP 2025 ITP Assessment: Enhancing Transmission Planning for a Resilient Energy Future

What is the 2025 ITP?

Key Elements of the 2025 ITP

Dual Futures Framework

Resiliency-Centric Planning

Updated Generator & Resource Models

Public Policy and Renewable Standards

Technical Depth: Key Metrics and Tools

Why This Matters for Keentel Clients

FAQs on the 2025 ITP Assessment Scope

1. What is the primary goal of the 2025 ITP?

2. Who oversees the 2025 ITP?

3. What are the planning years used?

4. What are Futures 1 and 2?

5. What are the key resiliency scenarios?

6. What is the Planning Reserve Margin (PRM)?

7. How are resources accredited?

8. How does SPP define “must-run” units?

9. What role do curtailment prices play?

10. What are hurdle rates?

11. How is resiliency need assessed?

12. What is the Southeastern SPP target area?

13. How is generation assigned in modeling?

14. What are generator prototypes?

15. How is storage modeled?

16. What is the role of Distributed Generation?

17. How are extreme events simulated?

18. How is LMP used for planning?

19. How does SPP handle load additions?

20. What are MEM and RMEM?

21. How is project value measured?

22. What is the ITP project timeline?

23. How are voltage stability and sensitivities handled?

24. How does SPP address evolving assumptions?

25. How can stakeholders participate?

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About the Author:

Sonny Patel P.E. EC

IEEE Senior Member

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