Currently storage of electrical energy in Australia consists of a small number of pumped hydroelectric facilities and grid-scale batteries, and a diversity of battery storage systems at small scale, used mainly for backup. To balance energy use across the Australian economy, heat and fuel (chemical Contact online >>
Currently storage of electrical energy in Australia consists of a small number of pumped hydroelectric facilities and grid-scale batteries, and a diversity of battery storage systems at small scale, used mainly for backup. To balance energy use across the Australian economy, heat and fuel (chemical energy) storage are also required.
A report from the Clean Energy Council (CEC) released in June 2024, titled The Future of Long Duration Energy Storage, noted that lithium-ion batteries (LIB) and pumped hydrogen energy storage (PHES) are currently the dominant energy storage systems for renewables in Australia. The CEC said emerging LDES technologies coupled with the energy
As Australia transitions to net zero, renewable energy storage is critical to ensure a secure, sustainable and affordable electricity supply. The report responds to common challenges around decarbonisation and technology readiness, examining the role of storage for seven sectors, and outlining the strengths and weaknesses of specific technology
Liquid air (LAES), zinc–bromine batteries (ZNBR), underground hydrogen and thermal energy storage systems are all being studied to meet medium-duration and grid-scale storage applications. LAES and ZNBR batteries are currently in pilot-scale demonstrations, while underground hydrogen and thermal energy storage systems require more time for
Pumped Hydro Energy Storage (PHES), Compressed Air Energy Storage System (CAES), and green hydrogen (via fuel cells, and fast response hydrogen-fueled gas peaking turbines) will be options for medium to long-term storage. Batteries and SCs are assessed as a prudent option for the immediate net zero targets for 2030–2050.
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In a speech in March this year, AEMC Commissioner Tim Jordan stated: "by AEMO''s current calculations, outlined in the ISP, 61 GW of storage capacity is needed by 2050 under the Step Change scenario. That''s 17 times current levels." Federal and state governments have announced various policies to stimulate battery investment, but challenges to their development are starting to emerge.
Here we take a look at current proposals for storage across the NEM and their implications.
AEMO''s Electricity Statement of Opportunities (''ESOO'') was published last month, and forecasts in its Central scenario some large storage projects to be operational by the end of 2032-33:
Converting decommissioned power stations into large-scale battery storage is proving an efficient way to capitalise on existing electrical infrastructure (e.g. switchyards). The AEC has produced a guidance report highlighting considerations for this type of project.
In addition to the ESOO-listed projects, which are considered advanced in nature, there are many new projects hoping to progress towards completion:
While there is no shortage of projects, it is still a long way away from the $64 billion of storage investment AEMO forecasts is needed in its Step Change scenario. This might be one reason why governments are stepping in.
In December 2022, energy ministers agreed to support the design of a Capacity Investment Scheme (CIS) in order to encourage investment in new dispatchable capacity into Australia''s energy grid. In August 2023, the Department of Climate Change, Energy, Environment and Water commenced consultation on the Capacity Investment Scheme.
The CIS aims to add $10 of investment to secure 6GW of "clean dispatchable capacity to the grid by 2030". On 29 June 2023, the Commonwealth and NSW governments announced that the CIS would support an additional 550MW of firmed renewable generation in the state. In the announcement, both governments cited the 3.3GW of capacity submitted to the NSW 380MW firming tender round as evidence of an appetite to install additional firmed renewables in NSW.
The scheme will operate through a series of competitive tenders, where the commonwealth will offer long-term underwriting agreements for an agreed revenue "floor" and "ceiling" or "collar" arrangement. In its August 31 submission to the Capacity Investment Scheme consultation paper, the AEC identified several complexities that arise because of the collar arrangement, namely:
The AEC has taken the view that the collar''s complexities outweigh its benefits to the market.
A simpler alternative might be one that provides only fixed competitive grants upon completion or paid progressively according to availability. Under this model, the government would have no trailing liabilities, and, after completion, all ongoing market risks would be retained by the capacity.
Source: Capacity investment Scheme Consultation Paper
The CIS will utilize the AEMO ISP and the ESOO to produce its own reliability modelling, though it seems certain elements of the modelling process could be improved to reflect the reality that the delivery of firm output is for the purpose of customers, and best located at load centres. The current proposed structure of the CIS allows states to specify that projects must be located within a declared Renewable Energy Zone (REZ). It would seem preferable for locational incentives to arise only through market design.
It is important to note that the CIS has proposed a minimum project size of 30MW (AEMO registered capacity). As part of the consultation process, DCCEEW is seeking feedback on the evaluation criteria it should implement to assess a project''s contribution to system reliability – that is, the project''s potential contribution to avoid unserved energy events and to the reliability standard.
On 28 September 2022, the Queensland government announced its $62 billion Queensland Energy and Jobs Plan which included plans for two new pumped hydro plans delivering up to 7GW of storage capacity. The plants are to be owned and run by a new entity called "Queensland Hydro." The two new plants are called Borumba (proposed to be constructed near the Sunshine Coast) and Pioneer-Burdekin (proposed to be constructed near Mackay).
An assessment and early works are scheduled at Borumba in the 2023 calendar year. The Queensland government has stated that it would like the Borumba project operational in 2030, though recent delays to Snowy 2.0 have made some wary about this prospect. Sensibly, the government has flagged that some coal-fired generation will need to remain in the grid until Borumba is commissioned.
Pioneer-Burdekin is listed as ideally operational in 2032. The Queensland Supergrid Infrastructure Blueprint suggests that Pioneer-Burdekin will be commissioned in two 2,500MW stages, with the second opening in 2035. The blueprint also highlights a significant amount of wind and solar generation in close proximity to Pioneer-Burdekin.
The plan also included a $500 million investment in grid-scale community batteries. This funding will support local communities to store exported excess rooftop solar.
Separately, the government is working on a Queensland Battery Industry Strategy. A consultation paper was released earlier this year. The Government has also flagged an Energy Storage Strategy for release in 2024.
While this pipeline of projects shows promise, the latest ESOO does deliver some slightly sobering news around timing and in particular, the likelihood of delay.
"AEMO has observed that the initial target delivery dates provided by developers of new generation and storage investments often have not accounted for delays that could occur during the project financing, planning, development and delivery stages of projects. To ensure the accuracy of its reliability outlook, AEMO now applies delays to reflect observed development and delivery risks of new projects in the reliability forecast."
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