As the proportion of renewable energy in the grid continues to grow pumped hydro energy storage offers a solution for greater reliability, write Nick West and Donald Vaughan of Entura. But can the business case for storage stack up?
The future is bright for pumped hydro in Australia and for storage in general. However, no energy solution can exist outside of the real and competitive pressures of the market. Technical viability and environmental benefits won’t be enough to get projects over the line if they can’t demonstrate their financial soundness.
So how can pumped hydro generate sufficient revenue to be attractive to investors? And will that revenue continue to be predictable enough over the longer term?
No doubt there are opportunities, but developers may need to explore a range of different revenue sources in both existing and emerging markets since the arbitrage opportunities of the past may not be present in the future.
Where to for energy arbitrage?
The traditional revenue source for pumped hydro is arbitrage – in other words, making the most of generating when the spot price is high and pumping when the spot price is low. But this relies on a certain level of predictable variability in the electricity market and for that variability to continue into the future.
The upcoming retirement of several coal-fired power stations and the continued investment in renewables are likely to cement a market in which variability in power generation and the consequent volatility in energy prices are the norm.
Forecasting revenue – no easy task
Financing an energy project requires a firm revenue forecast. Lenders may consider “firm” to be a 90% confidence limit, which means the developer must demonstrate that the project can generate a certain amount of revenue 90% of the time, or, say, in 9 out of 10 years. This means that a robust and reliable forecast of project utilisation must be made.
Forecasting revenue for an asset with a lifecycle of up to 100 years requires detailed modelling of a wide range of factors influencing the electricity market, including supply (factoring in new entrants, storage, retirements and developments in the thermal sector, etc), demand (including changes in industrial load, impacts of electric vehicles, etc), fuel prices, government policies, and bidding strategies for large-scale wind and solar projects.
A business case for pumped hydro relies on all the assumptions that go into regular power plant financial modelling and adds the complexity of arbitrage.
A further complication is the impact on market prices of the presence of the developer’s own project. In other words, how will the proposed project influence the market in which it participates?
For a storage project, the influence is likely to be both an increase in low prices and a decrease in high prices. If the market is robust enough and the proposed project is relatively small, the influence could be minor. However, a very large project is likely to influence the market to such an extent that the utilisation of the project may be significantly reduced, which would reduce project returns.
Building a bankable business case
How can the confidence in a forecast be increased enough for a lender to commit funding to a project, given that variance of any one of these assumptions could disrupt the revenue streams for the project? While the transition to a renewables-dominated market continues, it may be that lenders need assurance that other revenue streams exist to reduce the project risk.
- Price insurance: High price events in the electricity market will certainly continue to occur, but it’s impossible to predict their timing. Energy storage projects can provide insurance to exposed customers (such as retailers and major industrial customers) through a cap contract in a similar way to gas turbines and other peaking plant. In practice, this may mean that the storage project rarely operates unless the price regularly exceeds the cap.
- Network support services: Storage projects have the ability to provide network support services such as frequency control, inertia and fault level control. These services have increasing value in a grid with significant amounts of non-synchronous generation. At this stage, the markets for these network support services are very shallow and competition is increasing. However, the need for such services is likely to increase to the point where more significant markets are required.
- Renewable firming: Government energy policy continues to be fluid, yet under the proposed National Energy Guarantee it is possible that there will be value in providing firming services – in other words, pairing dispatchable generators (such as storage projects or open-cycle gas turbines) with intermittent renewable sources of energy to improve reliability.
- Behind the meter generation: Storage projects are exposed to market prices during both modes of operation (pumping/charging and generating). If, however, there was an option to pump/charge for “free”, wouldn’t that reduce the risk? Genex Power’s Kidston K2 Project will pair a 250MW pumped hydro facility with a 270MW solar PV farm. During the day, solar energy can be used to power the pumps in the pumped storage project. The pumped hydro project will then generate into the evening (and morning) peak. If the upper storage is charged during the day, the K2 solar project can generate into the Queensland market and realise the benefits of large-scale generation certificates (LGCs). Of course, this arrangement relies on sufficiently high prices during peaks to recover the additional cost of the solar farm, transmission losses and any LGC liability.
As our electricity mix evolves, so will the economics of storage. While forecasting revenue for storage projects in the Australian electricity market is still an uncertain business, there are many opportunities in both the existing and emerging markets to guarantee project revenues to a level sufficient to satisfy a lender’s requirements.