Interconnection Queue: Why 2 Terawatts of Clean Energy Can't Plug In

At a Glance

Concept: The mandated engineering and financial study process a new power plant must pass to ensure it will not physically overload or destabilize the existing high-voltage transmission grid.
Why it matters: Trillions of dollars are being poured into wind, solar, and battery storage to combat climate change and power hyperscale AI data centers. However, capital cannot deploy if the grid operator takes five years to approve the physical cable connection.
Who uses it: Regional Transmission Organizations (RTOs), Independent System Operators (ISOs), utility engineers, and independent power producers (IPPs).
Biggest takeaway: The Federal Energy Regulatory Commission (FERC) recognized this crisis and enacted Order 2023, forcing the industry to abandon its “first-come, first-served” model in favor of a “first-ready, first-served” cluster study model, designed to purge speculative phantom projects from the queue.

In Simple Words

Imagine a massive, high-speed highway (the electrical grid). A private company builds a giant new shopping mall (a solar farm) right next to the highway. The mall is fully constructed and ready to open, but before they can build the on-ramp to let cars onto the highway, the highway authority must perform a traffic study.

The authority has to ensure that opening this specific on-ramp will not cause a catastrophic 100-car pileup downstream. If the study proves the highway cannot handle the extra traffic, the mall developer is forced to pay for an extra lane to be added to the highway before they are allowed to open.

In the power sector, this is called the Interconnection Queue.

A decade ago, only a few massive coal or gas plants asked for “on-ramps” each year. The highway authority could easily study them one by one. Today, driven by cheap solar panels and massive AI data center demands, thousands of small and large renewable projects are demanding on-ramps simultaneously. The authorities simply do not have the engineers to run the math fast enough. By 2024, the waiting list grew so massive that it took an average of 4.5 years (55 months) just to get the permit to plug a fully funded power plant into the grid.

Why This Matters

The interconnection queue is the single greatest threat to the global energy transition and the artificial intelligence economy.

According to the Lawrence Berkeley National Laboratory (LBNL) “Queued Up: 2025 Edition” report, as of the end of 2024, there were roughly 10,300 projects actively seeking grid interconnection in the United States alone. This represents nearly 2,290 gigawatts (2.29 Terawatts) of generation and storage capacity—roughly double the entire existing capacity of the current U.S. power plant fleet.

For tech giants like Microsoft, Google, and Amazon, securing gigawatt-scale power for their new AI training clusters is an existential requirement. If they cannot secure grid interconnection in Virginia or Ohio, they are forced to look at rogue deployments—building massive data centers next to unregulated, off-grid gas plants, which directly violates their corporate “Net Zero” climate pledges. For energy investors, the queue represents massive capital risk. A developer can spend USD 20 million permitting a wind farm, only to be told in Year 4 of the queue that they must pay USD 150 million to upgrade a substation 50 miles away, instantly bankrupting the project.

The Big Picture

The regulatory architecture governing the U.S. electrical grid is strictly managed by the Federal Energy Regulatory Commission (FERC).

Historically, FERC allowed grid operators to assess projects serially (one at a time) using a “first-come, first-served” methodology. As the queue ballooned to over 2 Terawatts, this system broke down completely. In response, FERC issued Order No. 2023 (finalized in late 2023 and heavily implemented through 2024 and 2025). Order 2023 is a landmark reform that forcibly transitions the entire U.S. grid to a “first-ready, first-served” cluster study approach, backed by harsh financial penalties for speculative developers who clog the system.

Simultaneously, FERC Order 1920 (set to take full effect around June 2026) mandates that transmission providers must look 20 years into the future and proactively plan for regional grid upgrades, rather than reactively forcing individual power plants to pay for piecemeal network upgrades at the end of the queue.

HOW THE INTERCONNECTION QUEUE WORKS

Injecting hundreds of megawatts of electricity into a fragile, highly synchronized alternating current (AC) grid requires flawless mathematical modeling.

1. The Fundamental Problem: Speculative Bidding

Because entering the queue was historically cheap, energy developers treated it like buying a lottery ticket. A developer would submit 10 different interconnection requests for 10 different solar farms, knowing they only had the cash to actually build one. They simply waited to see which of the 10 requests got the cheapest grid upgrade bill, and then canceled the other 9. This speculative bidding created a massive “phantom queue” that grid engineers wasted years studying.

2. The Insufficiency of First-Come, First-Served (Serial Studies)

Under the old serial method, if Project A entered the queue on Monday, and Project B entered on Tuesday, the grid operator studied Project A first. If Project A dropped out of the queue in Year 3 because they ran out of money, the grid operator had to throw away Project B’s study and completely recalculate the math for Project B from scratch, creating a devastating cascading delay.

3. The Core Mechanism: The Cluster Study

FERC Order 2023 replaces serial studies with the Cluster Study Process. Instead of studying projects individually, grid operators group all projects submitted within a specific “window” into a single cluster. They study the electrical impact of the entire cluster on the grid simultaneously. If multiple solar farms in the cluster overload a specific transmission line, the cost to upgrade that line is divided proportionally among all the developers in the cluster, vastly accelerating the engineering math.

4. Technical Depth: Network Upgrades and LMP

When a cluster study reveals that the grid cannot handle the new power, the grid operator mandates a Network Upgrade (e.g., rebuilding a substation or restringing a high-voltage line). If the upgrade is not built, the new power plant will face extreme congestion. In wholesale electricity markets, congestion is priced using Locational Marginal Pricing (LMP). If a wind farm connects to a congested node, its localized LMP price can crash to zero or even negative territory, meaning the wind farm loses money every time it generates power.

5. Real-World Consequences: Readiness Milestones and Withdrawals

To kill speculative bidding, Order 2023 introduced brutal “Readiness Milestones.” Developers must now put up massive, non-refundable cash deposits and prove they actually own the land (“site control”) to enter a cluster. If they drop out late in the process, they face severe financial withdrawal penalties. This forced a massive purge. According to the 2025 LBNL report, over 700 GW of capacity actively withdrew from the queues in 2024 alone. While this “thinning of the herd” caused short-term restudy chaos, it permanently cleared the phantom projects, ensuring that only highly capitalized, shovel-ready infrastructure remains.

Real-World Applications

The interconnection bottleneck is forcing corporations to radically alter how they deploy physical infrastructure.

Data Center Co-Location: Hyperscalers like Amazon Web Services (AWS) can no longer wait 5 years for grid transmission upgrades. Instead, they are purchasing land directly adjacent to existing, fully interconnected power plants (specifically nuclear stations like the Susquehanna Steam Electric Station in Pennsylvania). By connecting “behind the meter,” the data center buys the power directly from the generator before it hits the public transmission grid, legally bypassing the FERC interconnection queue entirely.

Hybrid Solar-Plus-Storage: Wind and solar farms only generate power when the weather cooperates, but the grid operator must study them as if they are injecting power at absolute maximum capacity. Developers are solving this by adding massive lithium-ion battery banks to their solar farms. By sharing a single Point of Interconnection (POI), the battery acts as a shock absorber. The developer can mathematically guarantee the grid operator that the site will never exceed its localized limit, drastically lowering the network upgrade costs required to connect.

Grid-Enhancing Technologies (GETs): FERC Order 2023 explicitly mandates that grid operators evaluate alternative technologies during cluster studies. Instead of forcing a developer to pay USD 50 million to build a new transmission tower, utilities can now deploy Dynamic Line Ratings (DLR) or advanced power flow controllers. These IoT sensors unlock hidden capacity on existing wires for a fraction of the cost, bypassing the need to pour new concrete.

Economic & Strategic Impact

The financial mechanics of the interconnection queue represent a multi-billion dollar allocation of risk.

Historically, the “First Mover” was heavily penalized. If the grid needed a new high-voltage line, the unlucky developer who triggered the need was forced to pay 100% of the cost. Once built, subsequent developers could plug in for free. This “free-rider” problem destroyed project economics. The transition to proportional cost allocation under cluster studies distributes this financial burden equitably across all participants, making mega-projects financially viable again.

Strategically, the 55-month average wait time (as recorded in 2024/2025) acts as an artificial tariff on the clean energy economy. The U.S. Inflation Reduction Act (IRA) provided billions in tax credits to build wind and solar, but those credits are useless if the steel cannot connect to the wire. For sovereign wealth funds and private equity giants, a developer’s position in the interconnection queue is now the single most valuable asset on their balance sheet. A poorly funded solar project with a signed Interconnection Agreement (IA) will be acquired for a massive premium simply to obtain its legal right to plug into the grid.

Advantages (of FERC Order 2023 Reforms)

Eliminates Speculation: Strict financial penalties and site-control requirements prevent “phantom” projects from clogging the engineering pipeline.
Cost Sharing: Cluster studies allow multiple developers to split the cost of massive regional transmission upgrades, solving the “free-rider” problem.
Technology Integration: Explicitly allows hybrid storage models and advanced grid-enhancing technologies (GETs) to lower the cost of network upgrades without sacrificing grid reliability.

Limitations

The Transition Chaos: Switching from a serial queue to a cluster queue forces grid operators to temporarily pause new applications. During 2024 and 2025, many regions (like PJM) experienced “open window” freezes, severely stalling new greenfield developments.
The Talent Shortage: Moving to complex cluster studies requires advanced Electromagnetic Transient (EMT) modeling. There is a severe global shortage of electrical engineers trained to run these specific mathematical simulations, creating a human-capital bottleneck.
Does Not Build Wires: Reforming the queue only changes how we study the grid; it does not physically build new high-voltage transmission lines. Without massive, proactive regional transmission planning (addressed by Order 1920), the wires will remain physically full.

Common Misconceptions

Misconception: The grid operator is intentionally blocking renewable energy to protect fossil fuels.

Reality: Grid operators (ISOs/RTOs) are generally technology-neutral. Their legal mandate is to prevent the grid from collapsing. Injecting massive amounts of intermittent, inverter-based resources (like solar) into an old grid designed for spinning coal turbines physically threatens the voltage stability of the network. The slow math is an engineering necessity, not a political conspiracy.

Misconception: Being in the queue means the power plant is being built.

Reality: Most projects in the queue only exist on paper. Even with recent reforms, historically only about 19% of the projects that entered the queue actually survived to reach Commercial Operation Date (COD).

Misconception: The government pays for grid upgrades.

Reality: In most U.S. jurisdictions, the private energy developer pays for the specific network upgrades required to connect their plant. These costs are ultimately passed down to the consumer through the wholesale price of electricity, but the initial capital expenditure falls entirely on the private sector.

What Most People Miss

The hidden landmine in the interconnection process is the Affected System Study.

A developer might successfully pass the engineering studies for their specific grid operator (e.g., MISO in the Midwest). However, the electrical grid is physically interconnected. The neighboring grid operator (e.g., SPP or PJM) has the legal right to claim that the new power plant will push excess electricity across the border and overload their wires. The developer must then wait for an “Affected System Study” from the neighbor. Because these neighboring utilities operate on entirely different software systems and timelines, lack of coordination frequently causes multi-year delays that completely blindside fully funded projects at the 11th hour.

Comparison Table

Feature	Pre-2023 Legacy Queue (Serial)	Post-2023 Reformed Queue (Cluster)
Study Methodology	First-Come, First-Served (One by one).	First-Ready, First-Served (Group batches).
Upgrade Cost Allocation	“First Mover Pays.” The unlucky project pays 100%.	Proportional. Shared pro-rata among the cluster.
Entry Requirements	Low cost, easily refunded. Highly speculative.	High financial deposits, strict site-control proof.
Withdrawal Penalty	Minimal. Encouraged phantom projects.	Severe financial penalties to discourage dropping out.
Restudy Impact	Cascading delays affecting the entire queue line.	Contained within the cluster phase; mitigated by penalties.

Case Study

Situation: By the end of 2024, the U.S. interconnection queue reached a historic peak of approximately 2,290 GW of active capacity. The system was completely paralyzed. Developers were waiting over 55 months to connect, and grid operators were overwhelmed by the sheer volume of speculative solar and battery proposals.

Challenge: The Federal Energy Regulatory Commission (FERC) had to eradicate the speculative “phantom” projects without accidentally bankrupting legitimate, shovel-ready clean energy infrastructure, all while standardizing the engineering math across wildly different regional grids.

Solution (The Purge): FERC Order 2023 was enforced, shifting the grid to strict cluster studies and imposing severe financial readiness milestones. Developers who lacked the capital to actually build their projects were given an ultimatum: pay massive, non-refundable deposits to stay in the queue, or leave.

Outcome: The result was a violent, necessary market correction. According to the 2025 Lawrence Berkeley National Laboratory (LBNL) queue report, an unprecedented 700 GW of capacity actively withdrew from the queues in 2024 alone. This represented a 12% year-over-year decrease in total active queue volume—the first significant drop in a decade.

Lessons Learned: The 2024 withdrawal wave proved that the vast majority of the “queue crisis” was an artificial financial bubble, not just an engineering failure. By treating grid interconnection space as a scarce, highly penalized asset rather than a free lottery ticket, FERC successfully transitioned the industry from a volume-based bottleneck to a high-quality, executable pipeline.

Future Outlook

Next 12–24 Months

The industry will navigate the “Restudy Hangover.” As the 700 GW of phantom projects drop out of the system, grid operators must frantically recalculate the cluster studies for the legitimate projects that remained. While Order 2023 is officially the law of the land, the physical rollout across regional tariffs will remain bumpy. Expect a massive surge of finalized Interconnection Agreements (IAs) by the end of 2026 as the newly optimized clusters finally clear the regulatory hurdles, unlocking billions in stranded capital.

Next 3–5 Years

FERC Order 1920 will fundamentally reshape the landscape. Targeting a tentative compliance window of June 2026 and beyond, Order 1920 shifts the burden from the developer back to the grid planner. Transmission providers will be forced to plan regional upgrades 20 years in advance, incorporating dynamic load growth from AI data centers and electrification. This will effectively preempt the queue bottleneck; instead of developers waiting for the grid to react, the grid will be proactively reinforced to accept new generation before the power plants are even proposed.

Next 10 Years

The queue will transition from a manual, human-driven engineering process to a fully automated, AI-driven software platform. Electromagnetic Transient (EMT) models, which currently take human engineers months to run, will be processed by artificial intelligence in hours. Developers will be able to log into an ISO portal, drop a pin on a digital map, and instantly receive an AI-generated, perfectly accurate network upgrade cost estimate, turning grid interconnection into an instantaneous, frictionless digital transaction.

Most Likely Scenario

The 55-month wait time is the high-water mark of grid inefficiency. The brutal reforms of Order 2023, paired with the proactive planning of Order 1920, will successfully break the bureaucratic logjam. While the physical construction of new high-voltage wires will always be slow due to environmental permitting, the administrative and engineering math required to plug into the grid will be streamlined, ensuring that the 21st-century energy transition is not defeated by paperwork.

Key Takeaways

The interconnection queue is the mandatory engineering study process required to safely plug a new power plant into the high-voltage electrical grid.
By the end of 2024, nearly 2.3 Terawatts of capacity were trapped in the U.S. queue, with average wait times extending to 55 months (4.5 years).
The old “first-come, first-served” serial study method allowed developers to spam the system with speculative “phantom” projects, paralyzing grid engineers.
FERC Order 2023 forced the industry to adopt “cluster studies” and strict financial readiness milestones, leading to a historic withdrawal of 700 GW of speculative capacity in 2024.
Cluster studies allow multiple developers to proportionally share the multi-million dollar costs of upgrading regional transmission lines, solving the “first-mover penalty.”
To bypass the queue entirely, hyperscale AI data centers are increasingly purchasing power “behind the meter,” physically locating their campuses next to existing nuclear and gas plants.

Glossary

Affected System Study: An engineering analysis required when a new power plant connects to one utility’s grid, but the electrical impact spills over and threatens to overload a neighboring utility’s transmission lines.

Cluster Study: A methodology where grid operators group multiple proposed power plants together and analyze their cumulative impact on the grid simultaneously, drastically speeding up the engineering math.

Commercial Operation Date (COD): The official date when a newly constructed power plant has passed all grid tests and begins generating and selling electricity to the market.

FERC Order 2023: A landmark 2023 federal ruling that overhauled the U.S. interconnection process, mandating cluster studies, increased financial penalties, and proportional cost allocation.

FERC Order 1920: A sweeping federal rule requiring regional grid operators to conduct long-term, 20-year transmission planning using multiple plausible scenarios to proactively build grid capacity.

Interconnection Agreement (IA): The final, legally binding contract between a power plant developer and the grid operator that dictates the operational terms and network upgrade costs required to plug in.

Locational Marginal Pricing (LMP): The exact wholesale price of electricity at a specific physical node on the grid, which drops significantly if the local transmission lines are congested.

Frequently Asked Questions

Why does it take 55 months to approve a power plant connection?

Because the grid is a highly fragile, synchronized machine. Adding 500 megawatts of solar power changes how electricity flows across hundreds of miles of wire. Engineers must run thousands of complex mathematical simulations to guarantee that the new power will not blow up transformers or cause a cascading blackout during a heatwave.

What happens if a developer refuses to pay for a network upgrade?

They are forced to withdraw from the queue. Their project is canceled, they lose their initial financial deposits, and the grid operator moves on to the next project in line.

Can a solar farm just connect to the local neighborhood power lines?

Small rooftop solar systems connect to the local “distribution” grid without needing to enter the massive wholesale transmission queue. However, large, utility-scale solar farms (e.g., 100 megawatts) generate far too much electricity for local neighborhood poles; they must connect to the massive steel high-voltage “transmission” towers, triggering the full queue study process.

Did FERC Order 2023 fix the queue completely?

No. It fixed the administrative and mathematical bottleneck by clearing out speculative projects. However, it does not solve the physical bottleneck: the United States still fundamentally lacks enough physical high-voltage transmission wires to handle the localized power demands of the clean energy transition.

Why are battery projects dropping out of the queue?

While batteries are crucial for grid stability, standalone battery projects still require expensive interconnection studies. If the grid operator determines that the specific location cannot handle the rapid discharge of a massive battery bank without a USD 50 million wire upgrade, the battery developer will withdraw the project and seek a more profitable location.

Sources

Lawrence Berkeley National Laboratory (LBNL): Queued Up: 2025 Edition, Characteristics of Power Plants Seeking Transmission Interconnection (Released Dec 2025)
Federal Energy Regulatory Commission (FERC): Order No. 2023 – Improvements to Generator Interconnection Procedures and Agreements
Federal Energy Regulatory Commission (FERC): Order No. 1920 – Building for the Future Through Electric Regional Transmission Planning and Cost Allocation (May 2024/2026 Implementation)
Keentel Engineering: FERC Order 2023: Interconnection Reform Guide (2026)