Electrical Grid of the Future
Much is discussed about resurgent demand for electricity and this looks directionally correct. But this is a crude macro understanding of the power industry.
There are a series of 6 dynamics unfolding within the power generation and distribution sector that shape much of what is evolving. Future scenarios depend on what combination of these 6 dynamics actually emerge over time, and they tend to emerge in different places at different times.
1. Grid Services become the market, historically electricity markets were dominated by MWh of power generated and sold.
But in the future capacity and stability fees will come to dominate value; frequency control, reactive power support, black start capability, inertia emulation, and fast response balancing are all monetizable services that will expand as intermittent renewables expand their market share.
The grid is likely to see the volume price of the kWh rise sharply and then fall, and value capture evolves from units of power to grid services.
2. Intermittence Saturation, a synchronous grid (AC grid) can only absorb so much variable generation before the marginal value of the next solar/wind farm to be connected to the grid collapses.
Once curtailment and negative pricing begin, the limiting factor for delivering electrical power is not generation, but system elasticity.
Storage, flexible loads, and long distance interconnectors become the growth checks.
Beyond the saturation point where the marginal unit collapses the spot price, the grid flips from being generation limited to coordination limited.
Crucially as the market pricing flips to the new regime it opens up 3 types of arbitrage that provide a profit motive to drive coordination:
• Temporal arbitrage
• Geographic arbitrage
• Service arbitrage
Several grids worldwide already have zero or negative spot prices at the belly of the duck curve. This creates substantial arbitrage opportunity and moves all the value capture from generators to arbitrage providers.
3. Battery Energy Storage Systems - Temporal Arbitragers, intermittence opens an additional market for infrastructure + trader, physical and virtual assets can operate algorithmically to capture daily and even weekly price arbitrage opportunities. These can be regular (solar) and irregular (wind).
Increasingly we are seeing disruptive utility companies deploy fleets of BESS often financed by their own customer base.
4. Behind-the-Meter Revolution, households and businesses are becoming independent nano grids: rooftop solar + batteries + EV + intelligent load (including domestic robots working when power is cheap).
This BTM dynamic erodes retail demand whilst increasing self sufficiency. This likely has second order political effects strengthening demand for cleaner air and lower emissions.
Households will still be grid connected but grid consumption by households will be tempered by BTM, even as absolute power consumption increases.
The grid becomes more peaky, less predictable, with greater requirements for coordination.
Traditional utilities will lose volumetric sales, but will gain the ability to monetise residual grid access and balancing services.
Grid value allocation inverts from volume to services.
5. Long Distance HVDC spine, as renewables cluster around optimal geography (sun belts, wind corridors) and load concentrates around cities and datacenters long haul HVDC becomes the backbone energy infrastructure of civilisation.
Expect continental scale spines, North South for seasonal arbitrage, as the intermittent saturation point (and marginal price collapse) varies with latitude and climate season. East-West HVDC spines provide diurnal arbitrage harvesting in competition with BESS.
6. Hyperscalers as anchor tenants, datacenters and AI training clusters and inference factories are effectively new industrial loads with $50-60bn of industrial capex adjacent to each GWe.
These sinks demand 24/7 power, ultra stable frequency, and geographic (and jurisdiction) optionality.
The high load density is already driving colocation and dedicated on-site power generation.
All of these trends are superimposed over one another and unless you isolate them in analysis you can draw some weird assumptions.
It's worth remembering that globally the world buys around $3.5 trillion of electricity every year, and around $2.6 trillion of that goes to generation and $900 billion goes to transmission. Whilst these figures look very likely to swell, the ratio is also likely to change.
Transmission costs are going to be less and less about moving electricity over some distance and increasingly about quality control of the electricity that is delivered. The transmission system's role is evolving from a transport system to a quality system, transmission markets and pricing will eventually follow suit.