Grid Decarbonization: Politics, Costs, and Nuclear Battery

The Westinghouse eVinci nuclear battery concept has progressed significantly from its initial rough design. Previously, the reactor was estimated to be 12 to 15 feet high. The updated design now features five modules: a reactor module, a power conversion module, and at least three control modules. This new design appears considerably larger, illustrating the engineering challenges and cost escalation that occur when moving from concept to reality.

Cost Reduction in Nuclear Microreactors

Previous discussions touched upon cost reductions based on production rates rather than the total number of units produced, particularly for factory fabrication benefits. A comparable study on stationary fuel cells, which are similar to batteries but more complex, found a 30% cost reduction for every tenfold increase in production rate, at least initially.

However, a more recent study specifically for nuclear microreactors suggests a 20% cost reduction for every 100-fold increase in production (two tenfoldings). This translates to approximately a 9% reduction per tenfolding, indicating that earlier calculations might have been overly optimistic. For instance, an initial projection suggested a 45% cost reduction at 50 units per year, but revised numbers are less favorable.

The Evolution of the Electric Grid

Early Days: DC and Local Grids

The first central generator for electricity distribution was established in Wall Street, New York, in 1882. At that time, electricity was a luxury, costing about 100 times more than today's prices (adjusted for inflation). Early distribution used direct current (DC).

DC transmission faced significant limitations due to ohmic losses. For example, supplying a house a mile away with 1 kilowatt at 100 volts (10 amps) using a 10 AWG copper wire (1 ohm per thousand feet, totaling 10 ohms for a round trip mile) would result in a 50% power loss. This meant DC grids were very small, serving only local customers.

The AC Revolution: Transformers and Long-Distance Transmission

The invention of AC transformers revolutionized electricity distribution. Transformers allow for voltage changes, preserving power over long distances. By stepping up voltage to 100 kilovolts, the same 1 kilowatt of power could be transmitted with only 10 milliamps of current, reducing power loss to 0.1% over the same distance.

This breakthrough enabled long-distance transmission and the development of large-scale power stations. The first such station was a hydro plant at Schoellkopf Mills near Niagara Falls, which powered Buffalo, New York, 20 miles away. Early transmission voltages were around 66 kilovolts, gradually increasing to 765 kilovolts today, with discussions about even higher voltages.

Economies of Scale and Monopolies

The ability to transmit electricity over long distances led to economies of scale. It became more economical to build large central power plants (coal, natural gas, nuclear) and transmit power to distant customers than to have numerous smaller, regional plants. This resulted in a "hub-and-spoke" architecture that still dominates today.

Consequently, the companies building these plants became large, vertically integrated monopolies, owning everything from generation to transmission and distribution. These regional monopolies had complete control over electricity supply and pricing.

Consequences of the Hub-and-Spoke Architecture

1. Vulnerability: The centralized architecture is susceptible to single points of failure. The grid is fragile, with transmission lines vulnerable to natural events and accidents.
2. Price Fixing: Vertically integrated monopolies could engage in price fixing due to a lack of competition.
3. Unfriendly to Distributed Generation: This architecture is ill-suited for distributed generation sources like wind and solar, as power lines are designed to flow back to central points. Moving power from distributed sources is challenging within this framework.

Regulation and Price Control

By 1900, electricity prices were exorbitant ($6 per kilowatt in today's dollars), hindering expansion. During the Great Depression, the US government intervened, creating regulators to prevent monopoly pricing. This led to a dramatic price drop to $0.88 per kilowatt by 1932, increasing access to electricity and aiding economic recovery. This highlights the importance of regulation in preventing monopoly pricing and the critical role of cheap power in economic growth.

Grid Expansion and Blackouts

Between 1920 and 1960, the grid expanded enormously. The US grid is split into three synchronous zones, with Texas and Alaska having their own independent grids to avoid federal oversight.

A major blackout in 1965 revealed the instability of an unregulated grid where entities could push power onto the system without coordination. This led to the creation of two key organizations:

• FERC (Federal Energy Regulatory Commission): A government entity that sets rules for economic competition and electricity pricing.
• NERC (North American Electric Reliability Corporation): A non-profit organization created after the 1965 blackout to establish rules for grid reliability, power flow management, and inter-entity communication. NERC's rules are technically voluntary but widely followed due to the necessity of grid operation.

The "Private Cloud" and Regulatory Cementation

These regulations, paradoxically, cemented the existing system of regional monopolies. While aiming to prevent monopoly pricing, they didn't prevent monopolies themselves. The electric grid is often considered a "natural monopoly" where multiple competing infrastructure networks would be inefficient.

The regulatory apparatus made it difficult for small startups to enter the market, effectively forcing them to sell out to larger companies. This created a "private cloud" where large utilities negotiated prices with state regulators, leading to a lack of pressure for efficiency or cleaner generation.

Deregulation and Independent System Operators (ISOs)

Academics proposed a free-market approach, where independent generators would compete to sell electricity onto a non-discriminatory grid, driving down prices. This led to FERC Order 888, which mandated that private monopolies establish Independent System Operators (ISOs) or Regional Transmission Organizations (RTOs).

ISOs/RTOs operate markets for electricity, dispatch generators, oversee transmission, and enforce NERC reliability standards. They are responsible for ensuring the grid is available to all independent companies.

Impact of Deregulation

• Unchanged Prices: Despite expectations, deregulation did not significantly reduce electricity prices. The reasons for this remain a subject of economic debate.
• Increased Competition: Deregulation did allow more competitive generators, particularly wind and solar, to enter the market due to their low marginal costs. These technologies are more prevalent in deregulated regions.
• Discriminatory Practices: While ISOs are supposed to be non-discriminatory, the interaction between NERC rules, grid architecture (hub-and-spoke), and the characteristics of variable generation (wind, solar) can make it difficult for these sources to connect and maintain reliability. This effectively slows down the deployment of wind and solar.

Grid Expansion Challenges

The Need for Expansion

Variable generation (wind and solar) requires more grid capacity to move electricity around. Economic models, such as the Shaner model and the MIT Future of Nuclear Power study, indicate a significant role for wind and solar in future energy mixes.

Cost of Storage

The Shaner model, which explores the feasibility of a 100% renewable grid, found that 12 hours of storage could lead to a reasonable cost of around $150 per megawatt-hour. While 12 hours of lithium-ion storage would cost approximately $1 trillion at current prices, this is within the scope of national budgets (e.g., half the cost of maintaining nuclear weapons over 10 years). Current production rates could supply this storage within five years.

Who Pays for Grid Expansion?

Currently, wind and solar developers are often burdened with the costs of grid expansion needed to connect their projects. Existing utilities, which own older fossil fuel plants, have little incentive to support grid expansion that would enable cheaper wind and solar to undercut their business. They often keep the grid operating at the edge of NERC stability requirements, forcing new renewable projects to pay enormous sums for grid upgrades.

Externalities and Moral Dilemmas

Operating the grid close to its margin increases vulnerability to events like hurricanes and wildfires, leading to more brownouts and blackouts. Society pays for this reluctance to expand the grid through reduced reliability and increased costs.

Internationally, many countries (UK, EU, Australia, Canada, Korea) socialize the cost of major transmission lines through regulated tariffs, while new plants pay for local connections. Japan has a "reeling tariff" for new generators. The US approach, where new generators bear the full cost of grid upgrades, is an outlier and may explain slower renewable deployment despite abundant resources.

FERC Order 1920 and Political Opposition

FERC Order 1920, issued last year, aims to align the US with international practices by requiring long-term regional transmission planning and cost allocation. However, it is currently suspended and challenged in court by a coalition of 19 Republican-led states, including Texas. These lawsuits, likely backed by established fossil fuel interests, aim to block wind and solar expansion.

Transmission Queue and Permitting Delays

A significant number of wind and solar projects are waiting in the grid connection queue. Many of these projects (around 75%) are eventually withdrawn due to the long wait times (averaging 13 years) and high costs. The point of interconnection charge is typically less than $50 per kilowatt, but network upgrades can cost $200-$300 per kilowatt. The primary barrier is the queue length, not necessarily the direct cost.

Permitting and right-of-way costs account for 25-30% of a transmission project's total cost. Building transmission lines is slow: only 70 miles of 765-kilovolt lines have been installed since 2010, compared to 100,000 miles of natural gas pipelines. This disparity is due to differing permitting processes: power lines require negotiation with numerous federal, state, and local entities, while natural gas pipelines have a single point of contact for federal authorization, reducing permitting time from 13 years to two.

Proposed legislation to streamline power line permitting, similar to natural gas pipelines, has been stalled by Congress.

Cost of Transmission Expansion

Estimates for transmission line construction range from $4 million to $5 million per mile for a 500-kilovolt line. Studies by NREL and others often project lower costs, but historical data suggests these estimates are typically 20-50% optimistic. Large projects, like a 1,500-mile line from the Great Plains to California, could cost $9 billion, comparable to a nuclear power plant. These lines can carry 4-6 gigawatts of continuous power, primarily to manage excess generation and stabilize the grid.

NREL's 2024 National Transmission Planning Study

This study claims that every dollar spent on transmission yields $1.60-$1.80 in savings, totaling $270-$490 billion by 2050. It also projects 10-11 billion metric tons of CO2 abatement, equivalent to 115 nuclear plants operating until 2050.

The savings primarily come from avoiding fossil fuel use, as existing wind and solar can operate at higher capacity factors (40% for wind, 28% for solar) by shifting power. However, the study assumes the addition of 770 gigawatts of wind and 1000 gigawatts of solar by 2050, which is highly optimistic.

The study suggests an additional cost of $80-$200 per kilowatt of capacity for wind and solar due to grid requirements, representing 4-14% of their overnight cost. Even if these figures are doubled due to optimism, the cost remains manageable and does not fundamentally alter the competitiveness of these technologies.

Realism of Grid Expansion

The required grid expansion for a high-renewable future faces significant institutional and political hurdles:

• Institutional Optimism: The NREL study projects 170,000 miles of 765-kilovolt lines by 2050, a massive increase compared to the 70 miles installed in the last decade. This scale of growth is institutionally unrealistic.
• Supply Chain Limitations: There are likely insufficient manufacturing capacities for power transformers, transmission towers, insulators, and other equipment within the US.
• Operational Complexity: Operating such a vast and interconnected grid, especially with high-voltage DC lines, presents unprecedented operational challenges.
• Cost Socialization: Without policies like FERC Order 1920 to socialize costs, individual renewable projects cannot bear the burden of massive grid upgrades.
• Permitting and Rights of Way: The 13-year average permitting time for transmission projects, coupled with NIMBYism and the high cost of rights of way (30% of project cost), severely impedes progress.
• Political Obstruction: Political opposition, often fueled by fossil fuel interests, actively works to block transmission expansion. The Trump administration's cancellation of federal loan guarantees for transmission projects is an example.

Conclusion

Decarbonizing the grid is not a technological problem; the necessary technologies exist. It is primarily a legal and political problem. While studies suggest significant economic and environmental benefits from grid expansion, political battles, regulatory frameworks, and entrenched interests are holding back progress.

Nuclear power, which does not require the same extensive transmission architecture as distributed renewables, benefits from this stagnation. The future of grid decarbonization depends heavily on political will, policy reforms, and the outcome of future elections to streamline permitting and socialize transmission costs. Without these changes, progress will likely be slow and incremental, with continued reliance on fossil fuels.