Grid reinforcement options assessment embeds systematic comparison of conventional network expansion with options that can increase the capability of existing infrastructure within the planning process. Rather than treating a new line or substation as the default response to an emerging constraint, network planners assess options such as reconductoring, dynamic line ratings, power-flow control, storage, switching and other technologies alongside conventional reinforcement.  

Options are evaluated using consistent criteria such as cost, reliability, transmission losses, right-of-way requirements and operational impacts. In some cases, upgrading or operating existing assets differently can increase network capacity faster or at lower cost than constructing new infrastructure.  

Embedding this comparison within formal planning processes makes consideration of reinforcement options systematic rather than discretionary and provides regulators and stakeholders with greater transparency over investment decisions. The approach does not eliminate the need for new infrastructure, but helps ensure that network investment decisions reflect a consistent assessment of credible options.  

Main Outcomes of the Solution 

• Reliability & Flexibility: Enables greater use of existing network capacity and more options for managing changing power flows while maintaining reliability standards.  
• Affordability: Identifies opportunities to defer or avoid higher-cost infrastructure investment through better use of existing assets.  
• Institutional Efficiency & Transparency: Creates a systematic and transparent process for comparing reinforcement options and supporting investment decisions. 

Key Deployment and Scaling Factors 

1. Require credible reinforcement options to be considered systematically within network planning processes. 
2. Establish comparable cost, reliability and operational methodologies to evaluate different options on a consistent basis. 
3. Ensure sufficient network data and modeling capability to quantify the capacity, reliability and operational impacts of each option. 
4. Define transparent selection criteria so regulators and stakeholders can understand why an investment was chosen. 
5. Ensure telemetry, communications, control-system integration and cybersecurity requirements are addressed where solutions depend on real-time monitoring or active network control. 
6. Periodically reassess options as demand, generation patterns, system conditions and technology costs change. 

Case study 

Federal Energy Regulatory Commission (2024), Unites States of America 

In May 2024, the Federal Energy Regulatory Commission (FERC) issued Order No. 1920, reforming long-term regional transmission planning and cost allocation in the United States. The rule requires transmission providers to develop at least three distinct long-term scenarios using a planning horizon of no less than 20 years and to reassess those scenarios at least every five years. FERC subsequently issued Orders No. 1920-A in November 2024 and 1920-B in April 2025, modifying and clarifying certain requirements while retaining the long-term planning framework.  

The framework requires transmission providers to consider whether four specified alternative transmission technologies – dynamic line ratings, advanced power-flow control devices, advanced conductors and transmission switching – could address regional transmission needs more efficiently or cost-effectively. This includes considering their incorporation into existing transmission facilities as an alternative to other potential transmission facilities and their incorporation into proposed regional transmission facilities. Transmission providers must also explain how these technologies are considered, increasing transparency for stakeholders.  

The reform therefore embeds consideration of technologies that can increase the capability of existing infrastructure within regional transmission planning alongside conventional transmission investment. 

Central Electricity Authority (2024), India 

India’s Central Electricity Authority (CEA) incorporates different reinforcement options within its transmission planning criteria. For transmission network strengthening, the Manual on Transmission Planning Criteria requires planners to study cost, reliability, right-of-way requirements, transmission losses and downtime, including when considering upgrading and reconductoring existing lines. Where necessary, new transmission lines or substations, including adoption of a higher voltage level, may also be explored.  

This framework places upgrading and reconductoring within the assessment of transmission strengthening options rather than assuming that new infrastructure is the only response to network constraints. The CEA published the Manual on Transmission Planning Criteria (with Amendment-I) 2025 in January 2025, maintaining this framework as part of India’s transmission planning criteria. 

References:

1. Transmission Planning and Cost Allocation Final Rule | Federal Energy Regulatory Commission   
2. Order No. 1920 Fact Sheet | Federal Energy Regulatory Commission  
3. Manual on Transmission Planning Criteria (with Amendment-I) 2025 | Central Electricity Authority