Grid-Enhancing Technologies for Data Centers: What Developers Can Use Before New Transmission Arrives
GETs will not solve the power crisis, but they can change the near-term site strategy.
Grid-enhancing technologies, or GETs, are tools that increase the usable capacity of the existing transmission system without waiting for entirely new lines. For data center developers, the important categories are dynamic line ratings, advanced power flow control, topology optimization and advanced conductors. They do not create unlimited power. They can, however, unlock capacity in constrained corridors faster than traditional transmission buildouts.
That matters because data center demand is moving faster than the grid. JLL's 2026 Global Data Center Outlook projects roughly 97 GW of new global data center capacity between 2025 and 2030 and says the sector may require up to $3 trillion in combined real estate and IT infrastructure investment by 2030. New transmission is necessary. It is also slow.
What GETs actually include
The Center on Global Energy Policy at Columbia University defines grid enhancement solutions as commercially ready technologies that can unlock additional capacity from existing infrastructure, often in months rather than years. The main tools are practical, not speculative.
Dynamic line ratings use real-time weather, wind, temperature and line condition data to determine how much power a transmission line can safely carry. Static ratings are conservative. Dynamic ratings can show that a line has more usable capacity under actual field conditions.
Advanced power flow control uses devices that redirect electricity away from overloaded paths and onto underused parallel routes. The analogy is traffic routing, but for electrons.
Topology optimization uses software to recommend grid switching configurations that relieve congestion. It can find a better operating pattern without new steel in the ground.
Advanced conductors replace older transmission line materials with higher-capacity conductors, often using existing rights-of-way. That does require physical construction, but it can be far faster than permitting a new corridor.
For a developer, the takeaway is simple: not all grid capacity improvements require a decade-long transmission project.
Why this matters for data center sites
Data centers are not normal commercial loads. They are large, flat and increasingly urgent. EIA noted in 2024 that AWS contracted for up to 960 MW tied to Talen Energy's Susquehanna nuclear plant, while Microsoft signed a 20-year PPA tied to Constellation's planned restart of Three Mile Island Unit 1. These are power plant-scale commitments.
Most developers cannot solve that by waiting in a queue. They need to know whether the local grid can support staged energization, whether transmission bottlenecks can be relieved and whether the utility has a credible plan to serve load before the tenant's required date.
GETs matter most in three situations:
A site has generation nearby but transmission congestion blocks deliverability
A utility has load growth pressure but limited appetite for new rights-of-way
A developer needs an interim capacity path before larger upgrades arrive
They matter less when the constraint is local distribution, substation equipment, transformer availability or generation adequacy. GETs can improve transmission utilization. They do not replace a missing transformer or an unbuilt substation.
The numbers are meaningful
The Columbia paper cites several deployed examples. National Grid in the UK reported that dynamic line rating technology across 275 kilometers of transmission enabled service to roughly 75,000 additional homes annually and delivered an estimated £20 million per year in consumer savings. Belgium's Elia reported dynamic line rating installations increasing transmission capacity by about 30% more than static capacity over 90% of the time. PPL Electric Utilities in Pennsylvania reported congestion reductions of up to 65% on monitored lines and more than $50 million in transmission congestion savings.
Advanced conductors can also be material. Columbia cites examples where reconductoring increased line capacity by more than 40% in California and nearly doubled capacity in Texas. These are not lab concepts. They are field-deployed tools.
What AI can do in the evaluation
AI is useful because the relevant evidence is fragmented. A power strategy may require transmission maps, utility integrated resource plans, FERC filings, interconnection queue data, ISO congestion data, state commission dockets, local substation records and vendor information. No one source answers the question.
An AI workflow can:
Identify constrained transmission corridors near target sites
Extract load-growth assumptions from utility plans
Track FERC and state commission filings mentioning GETs
Compare utility adoption of dynamic line ratings and topology optimization
Flag where advanced conductor projects are planned or funded
Build a site-level power risk memo with sources
Utility engineers, power market advisers and interconnection specialists still need to validate whether the technology can support the required load.
How developers should use GETs in site selection
GETs should not be treated as magic capacity. They should be one line in the power diligence model. A practical screen asks whether the constraint is transmission, distribution, substation equipment or generation, whether the utility has deployed GETs before and whether capacity gains can support phased energization while larger upgrades are built.
A GET deployment may increase system capacity, but it does not automatically allocate that capacity to a specific project. The commercial, regulatory and queue-position mechanics still matter.
The honest limitation
GETs are a bridge, not the bridge. They can improve utilization of the grid we have. They cannot remove the need for new generation, substations, transformers, transmission lines and demand flexibility.
For data center developers, that makes them strategically useful. In a market where new transmission can take 7 to 10 years, a technology that can unlock capacity in months or a few years changes the underwriting conversation. It can turn a dead site into a phased site. It can also expose when a utility's claimed capacity path is more aspiration than plan.
The strongest development teams will not ask only, 'Where is the nearest power?' They will ask, 'What grid interventions make this load deliverable, who controls them and when can they be proven?'