Mar 25 2021

New US modelling points to solar

New modelling is behind an assessment that finds renewable generation is likely to account for as much as 60 per cent of new capacity in the US grid in coming decades.

The new levelised cost of electricity (LCOE), levelised avoided cost of electricity (LACE) and the levelised cost of storage (LCOS) modelling, forms part of the US Energy Information Administration’s (EIA) most recent annual energy outlook report.

New EIA modelling

LCOE reflects the cost to build and operate a power plant per unit of generation, annualised over the cost-recovery period, while the LACE represents a new power plant’s value to the grid.

It’s the first time the EIA has included LCOS in its modelling, and while similar to LCOE, it considers whether the storage is contributing to generation or drawing electricity from the grid, so it is calculated based on whether the battery is used to supply the grid or providing services.

Because LCOE and LCOS don’t capture all factors that contribute to actual investment decisions it makes direct comparisons across technologies challenging and, according to the EIA, misleading as a means to assess the economic competitiveness of alternative generation.

That’s why the EIA also outlines economic competitiveness by considering the value of the plant in serving the grid – this is the LACE.

“This provides a proxy measure for potential revenues from sale of electricity generated from a candidate project displacing (or the cost of avoiding) another marginal asset.”

The EIA adds the value over a project’s financial life and then converts the total into an annualised value by dividing by the projected average output of the project.

While more challenging to calculate, it provides a “more intuitive indication of economic competitiveness for each technology” than just LCOE or LCOS when looking at a range of technologies that could be used.

LACE-to-LCOE and LACE-to-LCOS is calculated to give a value-cost ratio for all generation technology to establish which project would give the most value compared to its cost. Projects with a ratio greater than one – LACE is greater than LCOE or LCOS – are considered the most attractive to build.

“Estimating LACE is more complex than estimating LCOE or LCOS because it requires information about how the grid would operate without the new power plant or storage facility entering service.”

EIA calculates LACE based on the marginal value of energy and capacity that would result from adding a unit of a given technology to the grid.

It takes account of both daily and seasonal variations in demand and the make-up of the existing generation fleet. It compares potential new generation against the mix of new and existing capacity that would be displaced. Wind generation that displaces gas-fired peaking capacity would have a different value to wind that pushed out Combined Cycle Gas Turbines (CCGT) or coal-fired generation with low fuel costs.

Assessment findings

In its latest assessment the EIA found the capacity-weighted average value-cost ratio is more than one for both stand-alone solar (defined as solar PV with single axis tracking) and hybrid solar PV (which includes a four-hour battery storage system) in 2026  (see figure 1 below). 

As a result, they are considered the most likely to be built in favourable regions. CCGT plants with a value-cost ratio of one is likely to be attractive for marginal capacity addition. Geothermal, which also has a value-cost ratio above 1, is limited by available resources. For example, the US only has 2.5GW of operating geothermal capacity and nearly all is in California and Nevada. Last year it produced about 0.5 per cent of the electricity generated, according to the EIA.

Obviously, this approach will not capture all factors behind a potential decision to build – there may be mandated targets for renewables, future environmental policies, fuel price shocks, government underwriting, or the need for reliability. All these will influence investment decisions, but the EIA believes it gives a greater insight for forecasting than LCOE or LCOS alone can provider.

The value-cost ratio for new resources (weighted and unweighted) is shown in the following figures.

Figure 1: Value-cost ratio (capacity weighted) for new resources entering service 2026

Source: EIA

Figure 2: Value-cost ratio (unweighted) for new resources entering service 2026

Source: EIA

Figure 3: Value-cost ratio (capacity weighted) for new resources entering service 2040

Source: EIA

Figure 4: Value-cost ratio (unweighted) for new resources entering service 2040

Source: EIA

Overall, the EIA expects revenues from electricity generated from both natural gas-fired combined-cycle units and solar PV to be generally greater than, or equal to, their respective projected costs across most of the electricity market regions.

Its annual energy outlook forecasts that generating capacity could increase by 52-84 per cent by 2050, with the majority of the new capacity expected to come renewables. Solar in particular is tipped to lead the way rather than wind as shown in Figure 5. 

The value of wind approaches its cost in several regions, and where this is the case new capacity can be expected to be developed. This will primarily occur ahead of the expected phaseout of the production tax credit (PTC).

The PTC is a per-kilowatt hour (kWh) credit for electricity generated by eligible renewable sources. It was introduced in 1992 but has been extended and modified since then. At the end of December 2020, the US Congress extended the PTC for onshore wind at 60 per cent of the full credit amount, or $0.018/kWh ($18/MWh) until 31 December 2021. The PTC will be reduced to zero starting in 2022. There was also an extension through to 2025 for offshore wind investment tax credits.

It’s worth noting that while the overall generating capacity in this period could increase by two-thirds or more, actual net generation is expected to increase by only a third, which would reflect the expansion in renewables.

The business case for gas, based on the modelling, also leads to the EIA assessment that gas-fired generation will account for almost all of the 40 per cent of new increased capacity that does not come from renewables. The US has plentiful gas supplies and as noted recently by Australia’s former chief scientist Dr Alan Finkel, gas can play a role particularly as more renewables come into the system.

Gas investment shifts

Of course, ultimate investment decisions will be affected by factors, such as policy shifts, that sit aside from a project’s value relative to its costs. This latest assessment is made on the basis of existing policies. Where the outlook for gas may be challenged is through President Biden’s aim to achieve a fully renewable grid by 2035 - although equally the politics of achieving that ambition still has a long way to run, particularly with a 50-50 Senate and potential for a filibuster. 

If ultimately a much easier net zero target became the end game, there would continue to be a role for gas given the economic case and generation mix.

Figure 5: Annual electricity generating capacity additions and retirements (reference case)

Related Analysis


Every step counts: China’s marathon journey to become net-zero

In 1971, when asked to assess the influence of the French Revolution, Chinese Premier Zhou Enlai famously remarked that it is ‘too early to say’. So it is not surprising that after President Xi announced China’s aim to be net-zero by 2060, some commentators framed it as ‘the start of a marathon, not a sprint’. But is this assessment fair?

Apr 01 2021

Capacity markets: The answer to extreme weather?

The fallout from the Texas blackouts has continued with the question of system reliability front and centre and, along with it, whether a mechanism like a capacity market could have led to a different outcome. We take a look at the US experience along with some of the issues it raises.

Mar 04 2021

The best little blackout in Texas

They say everything’s bigger in Texas. The major power outages from which it is just emerging, were triggered by a polar vortex and impacted around 4.5 million customers. There's been plenty of finger pointing with intermittent renewables being blamed, questions raised about Texas’s go-it-alone attitude and claims of poor preparations stemming from a deregulated energy market.

Feb 25 2021
Do you have a question or comment for AEC?

Send an email with your question or comment, and include your name and a short message and we'll get back to you shortly.

Call Us
+61 (3) 9205 3100