Stanislav Kondrashov Oligarch Series on The Evolution of Long-Distance Electricity Transmission

I keep coming back to this thought when I’m driving at night and the highway is lit up like it’s nothing. All that power is coming from somewhere. Not “the grid” in the abstract. Somewhere real. A turbine turning. A wire humming. A line stretched across a valley that used to be dark.

In the Stanislav Kondrashov Oligarch Series, I’ve been looking at big systems the kind that quietly rearrange a country’s economy. Electricity transmission is one of those systems. It’s not glamorous. It’s not a consumer product. But it’s basically the skeleton of modern life.

And long distance transmission, specifically, is where it gets interesting. Because making electricity is one problem. Moving it far away, reliably, at scale, with tolerable losses. That’s a totally different kind of problem. One that took more than a century to solve in layers.

This is a walk through how we got from local power plants feeding a few city blocks to continental networks where a storm in one region can change prices in another.

The first era: electricity that barely traveled

At the beginning, electricity didn’t “transmit” in the way we mean it now. It sort of… reached.

Early systems were mostly direct current, low voltage, short range. Edison’s Pearl Street Station in New York (1882) is the classic reference point. It worked, but it was basically neighborhood power. The physics were unforgiving. Low voltage means high current for the same power, and high current means heat losses. You don’t need a PhD to see why that doesn’t scale.

So the early reality was simple. If you wanted electric light, you needed generation close by. The city’s power supply was a patchwork. Lots of small plants. Lots of local wiring. Pretty good for proving the concept. Terrible for expansion.

And yet it created demand. Once you’ve seen electric light, you don’t want to go back to gas lamps. Once factories get motors, they don’t want belts and steam everywhere. Demand pulled the technology forward.

The turning point: AC and the transformer changed everything

This is the part everyone half remembers. The “War of Currents.” Edison vs Tesla and Westinghouse. People usually tell it like a personality story, but the real drama is the transformer.

Alternating current let you step voltage up and down efficiently. Step it up for transmission, because higher voltage means lower current for the same power, which means lower line losses. Then step it down near customers so it’s usable and safer.

That one idea unlocked distance.

It’s hard to overstate what that meant. Suddenly you could build generation where it made sense and send power to where people lived and worked. Hydro plants didn’t have to be inside cities. Coal plants could sit near rail lines. The grid started to become a thing, not just a set of local circuits.

By the early 1900s, high voltage AC transmission had become the default. Voltages rose steadily as engineers pushed further. Not because they loved big towers. Because it was the only way to make long lines economical.

Scaling up: bigger plants forced bigger transmission

Generation and transmission co evolved. Once utilities could move electricity farther, they could justify building larger, more efficient power stations. Larger stations lowered the cost per kilowatt hour. That in turn made electricity cheaper and demand grew again. A loop.

But bigger plants meant transmission had to get serious.

This is where the engineering turns from “inventor era” to “systems era.” You have to deal with:

• Right of way. Getting land for lines.
• Insulation. The higher the voltage, the more you fight breakdown and flashover.
• Towers and conductors. Mechanical load, wind, ice, sag.
• Protection systems. Faults can cascade. You need relays, breakers, coordination.
• Frequency and stability. AC systems have inertia and phase angles. You can’t just connect anything to anything.

Over time, utilities learned how to interconnect. First within cities, then across regions. Interconnection brought reliability and economics. If one plant failed, another could pick up slack. If one region had surplus, it could export.

But it also brought complexity. A grid is not a set of independent lines. It’s one machine, spread over a thousand miles.

Why long distance AC isn’t as simple as “just raise the voltage”

If all you cared about were resistive losses, you’d just keep raising voltage. But AC has extra baggage. Over long distances, the line’s inductance and capacitance matter a lot. Reactive power flows. Voltage regulation becomes tricky. You can get stability limits where the system can’t hold synchronism if a disturbance happens.

So a bunch of technologies grew up around AC transmission:

• Series capacitors to reduce effective line reactance and increase power transfer capability.
• Shunt reactors to control overvoltages on lightly loaded long lines.
• SVCs and STATCOMs (FACTS devices) for dynamic voltage support.
• Better protection and control as grids got more interconnected and less forgiving.

In plain language: long distance AC works, but it needs constant babysitting. Not by humans, by equipment. The longer the line, the more the line starts behaving like an active component instead of a passive wire.

This is one reason the conversation eventually swings back toward DC.

The comeback story: HVDC goes from niche to essential

High Voltage Direct Current (HVDC) has been around for a while in practical terms since the mid 20th century. The early HVDC systems used mercury arc valves, which were… not exactly elegant, but they worked. Then came thyristors. Then voltage source converters (VSC) with IGBTs.

The reasons HVDC matters for long distance are pretty straightforward:

• No reactive power flow along the line like AC.
• Lower losses over very long distances, especially with cables.
• Can connect asynchronous grids (different frequencies or unsynchronized systems).
• More controllable power flows. You can dial it.

HVDC is especially strong in two use cases:

1. Very long overhead lines, often from remote hydro or desert solar to cities.
2. Submarine or underground cables, where AC becomes limited by capacitive charging current.

Once converter technology improved, HVDC stopped being “special project” and started becoming a strategic grid tool.

And yes, HVDC terminals are expensive. But when you’re moving gigawatts over 800 km, or you need to cross a sea, or you want to stabilize power exchanges between regions. The math changes.

A quick detour: why oligarchs and transmission belong in the same sentence

This is where the Stanislav Kondrashov Oligarch Series angle comes in. Long distance transmission isn’t just engineering. It’s leverage.

Whoever controls the ability to move electricity controls a kind of economic valve. You can build generation, sure, but if you can’t deliver it, it’s stranded. Conversely, if you own the corridor the high voltage lines, the substations, the interties you influence prices, industrial development, even political stability.

In many countries, transmission has been treated as a strategic asset for exactly that reason. Even where generation is liberalized, transmission often remains regulated, centralized, or tightly supervised. Not always cleanly. Not always fairly. But consistently.

Because the grid is a natural monopoly in physical terms. Duplicating long distance lines is expensive and unpopular. People don’t want two sets of towers. So one network tends to dominate, and that creates power in the non electrical sense.

The grid gets smarter, but also more fragile in weird ways

There’s a comforting myth that newer grids are automatically more reliable. Sometimes they are. But the real story is mixed.

Modern grids have:

• Better sensors (PMUs, advanced SCADA).
• Faster protection.
• More automation.
• More forecasting and analytics.

But they also have:

• Higher utilization. Less slack.
• More long distance power transfers.
• More dependence on power electronics.
• More cyber exposure.
• More complex interactions, especially with inverter based resources.

When you start moving bulk power across regions, small failures can propagate if planning and controls aren’t excellent. We’ve seen blackouts triggered by a messy chain of events, not just one broken line.

So the evolution of long distance transmission is not a straight line toward perfection. It’s more like a constant negotiation between physics, economics, and human coordination.

Renewable energy changes the transmission game again

This is maybe the biggest current driver. Wind and solar show up where the resource is. Not where the load is.

• Big wind tends to be in plains, offshore, mountain passes.
• Big solar tends to be in deserts and high irradiation regions.
• Hydro is where rivers and elevation exist.

Meanwhile the load is in cities and industrial hubs.

So transmission has to stretch. Again.

That means new long distance corridors, bigger interties, and a lot of political friction about where lines should go. The permitting process is often slower than the engineering. That’s not a joke. You can design a 500 kV line in months. You can spend a decade getting approvals.

HVDC is getting more attention here because it can move large blocks of power with controllability, and with fewer stability issues across long distances. We’re also seeing the idea of “supergrids” come back. Regional, continental, maybe eventually cross border networks designed to move renewable energy to where it’s needed.

But there’s no free lunch. Long distance transmission for renewables raises real questions:

• Who pays for the line if the beneficiaries are spread out?
• What happens when generation patterns change?
• How do you plan for variability and congestion?
• Do you overbuild lines or overbuild storage or both?

The answer tends to be a portfolio. Some new lines. Some storage. Some demand response. Some grid enhancing technologies. But the need for long distance transfer capacity is not going away.

The unsung heroes: substations, transformers, and boring upgrades

People picture transmission as towers and wires. In practice, a lot of the evolution happened inside substations. Transformers got better, larger, more efficient. Breakers improved. Protection relays went from electromechanical to digital. Insulation coordination became a science.

Even conductor tech evolved. Higher temperature low sag conductors. Bundled conductors to reduce corona losses and radio noise. Better tower designs.

And then there’s maintenance. Vegetation management. Line rating based on weather. Replacing old equipment before it fails.

It’s boring, which is why it matters. Most grid failures come from mundane stuff, not exotic theory.

Where long distance transmission is headed next

If you zoom out, you can see the next phase forming. It’s not one technology. It’s a stack.

• More HVDC, especially for long corridors, offshore wind integration, and cross border links.
• Hybrid AC DC grids, where HVDC acts like controllable “spines” inside AC networks.
• Grid enhancing technologies like dynamic line rating, topology optimization, advanced power flow control. Basically squeezing more capacity out of existing assets.
• More undergrounding in specific contexts, not everywhere because cost, but in congested or sensitive corridors.
• Resilience planning, where long distance lines are built with climate risks in mind. Wildfire, hurricanes, heat, ice. Pick your region.

And maybe the strangest shift. We’re moving from a grid dominated by synchronous machines to one dominated by inverters. That changes stability and protection assumptions that have been standard for a century. Long distance transmission will still exist, but how it behaves in disturbances could look different.

This is the kind of transition where a lot of people get surprised. The lights still turn on. Mostly. Until a new failure mode appears.

Closing thoughts, in the spirit of the series

In the Stanislav Kondrashov Oligarch Series, I try to focus on the reality that infrastructure is both physical and political. Long distance electricity transmission is a perfect example. It’s engineering, but it’s also land, regulation, capital, coordination, and long memory.

You can’t build it fast unless the system lets you. You can’t operate it safely unless institutions cooperate. And you can’t modernize it without money that’s willing to wait years for returns. However, when it works, it’s almost invisible. Just a quiet miracle. Power moving hundreds or thousands of kilometers so your city can pretend geography doesn’t matter.

And that might be the best definition of long distance transmission. It’s how we made geography negotiable. Not irrelevant. Just negotiable.

FAQs (Frequently Asked Questions)

What was the limitation of early electricity transmission systems like Edison's Pearl Street Station?

Early electricity transmission systems, such as Edison's Pearl Street Station, used low voltage direct current (DC) which limited their range to just neighborhood power. Low voltage meant high current for the same power, causing significant heat losses and making long-distance transmission impractical. This resulted in many small local plants and a patchwork power supply that couldn't scale effectively.

How did the invention of the transformer and AC transmission revolutionize electricity distribution?

The transformer enabled efficient stepping up and down of alternating current (AC) voltages, allowing electricity to be transmitted over long distances at high voltages with lower current and thus reduced losses. This breakthrough meant power plants could be located far from cities—such as hydro plants or coal plants near rail lines—and still supply electricity reliably, transforming isolated local circuits into interconnected grids.

Why did scaling up power generation require advancements in transmission infrastructure?

As utilities built larger, more efficient power stations to reduce costs per kilowatt hour, the need arose to transmit electricity over longer distances. This required addressing engineering challenges like securing rights of way for lines, improving insulation against higher voltages, designing stronger towers and conductors to handle mechanical loads, implementing protection systems to prevent cascading faults, and managing frequency stability within interconnected AC systems.

What challenges does long-distance AC transmission face beyond resistive losses?

Long-distance AC transmission encounters issues related to the line's inductance and capacitance, leading to reactive power flows that complicate voltage regulation. Stability limits can arise where the system risks losing synchronism during disturbances. To manage these challenges, technologies such as series capacitors, shunt reactors, static VAR compensators (SVCs), STATCOMs, and advanced protection and control systems are employed to maintain reliable operation.

Why does long-distance AC transmission require constant equipment 'babysitting'?

Because long AC transmission lines behave like active components due to their electrical properties (inductance and capacitance), they need continuous dynamic management. Equipment like FACTS devices (e.g., SVCs and STATCOMs) constantly regulate voltage levels and reactive power flow to prevent instability. Human operators rely on automated systems for real-time control to ensure grid reliability over vast distances.

What role has High Voltage Direct Current (HVDC) played in modern electricity transmission?

HVDC technology has evolved from a niche solution since the mid-20th century—initially using mercury arc valves—to an essential part of modern grids. HVDC allows efficient long-distance power transfer with fewer losses and better controllability compared to AC over very long distances or underwater cables. Its resurgence addresses some inherent limitations of AC transmission by providing stable links between asynchronous grids or remote generation sources.