The original installation in 2017 was the largestlithium-ion battery in the world at 129MWh and 100MW.[1] It was expanded in 2020 to 194MWh at 150MW. Despite the expansion, it lost that title in August 2020 to the Gateway Energy Storage in California, USA.[2] The larger Victorian Big Battery began operations in December 2021.
During 2017 Tesla, Inc. won the contract and built the Hornsdale Power Reserve, for a capital cost of A$90 million, leading to the colloquial Tesla big battery name.[3][4][5]
In November 2019, Neoen confirmed that it was increasing capacity by a further 50MW/64.5MWh[6][7][8] to a combined 193.5 MWh. The increased storage capacity was installed by March 23, 2020, and the increased power[9] became operational in early September 2020.[10]
Construction
South Australia received 90 proposals and considered five projects to build a grid-connected battery to increase grid stability under adverse weather events.[11][12] This will enable less use of gas-fired generators to provide grid stability.[13]
Elon Musk placed a wager that the battery would be completed within "100 days from contract signature", otherwise the battery would be free.[14] Tesla had already begun construction, and some units were already operational by 29 September 2017, the time the grid contract was signed.[15][4] The battery construction was completed and testing began on 25 November 2017. It was connected to the grid on 1 December 2017.[14] The 63 days between grid contract and completion easily beat Musk's wager of "100 days from contract signature",[5][16][17] which started when a grid connection agreement was signed with ElectraNet on 29 September 2017,[4]203 days after Musk's offer on 10 March (in Australia).[5] Samsung 21700-size cells are used.[18]
Expansion
In November 2019, Neoen announced that it would increase the battery capacity by 50%.[19] The expansion cost €53 million ($A82 million,[20] whereas A$71 million had been expected), funded by A$15 million from the state government, A$8 million from ARENA and up to A$50 million in cheap loans through the Clean Energy Finance Corporation.[21][6]
The expansion was completed by Aurecon on 2 September 2020,[22] increasing its impact in the South Australia grid.[23] The battery receives $4 million per year for essential grid security services.[24] Johnson Winter Slattery advised the state government on its 100MW battery project, and expansion to 150MW.[25]
Operation
It is owned[26] and operated by Neoen, with the state government having the right to call on the stored power under certain circumstances.[27] Phase one provided a total of 129 megawatt-hours (460GJ) of storage capable of discharge at 100 megawatts (130,000hp) into the power grid, which was contractually divided into several parts, covering energy arbitrage, frequency control and stabilisation services. They included:[28][needs update]
70 MW running for 10 minutes (11.7 MWh) is contracted to the government to provide stability to the grid (grid services)[29] and prevent load-shedding blackouts[15][30] while other generators are started in the event of sudden drops in wind or other network issues. This service reduced the cost of grid services to the Australian Energy Market Operator by 90% in its first 4 months.[31][32]
30 MW for 3 hours (90 MWh) is used by Neoen for load management to store energy when prices are low and sell it when demand is high.[33]
On 14 December 2017, at 1:58:59 am, the Hornsdale Power Reserve (HPR) reacted when unit A3 at Loy Yang Power Station tripped. As its generators spun down over the next 30 seconds, the loss of its 560 MW of base power caused a dip in the system frequency. By 1:59:19, the frequency had fallen to 49.8 Hz, and triggered HPR's response, injecting 7.3 MW into the grid and effectively helping to stabilise the system before the Gladstone Power Station was able to respond at 1:59:27. This synchronverter reaction is a built-in feature, but had not previously been effectively demonstrated.[29]
On 25 May 2021, HPR has reported a successful real-life test of its new “virtual machine mode” by demonstrating an inertial response from a small selection of trial inverters, following the grid disturbances created by events in Queensland. After an upgrade in 2022, the battery has 2,000 MegaWatt-seconds (MWs) of grid inertia, about 15% of the state's total grid requirement.[34][35]
Revenues from operation
During two days in January 2018 when the wholesale spot price for electricity in South Australia rose due to hot weather, the battery made its owners an estimated A$1,000,000 (US$800,000) as they sold power from the battery to the grid for a price of around A$14,000/MWh.[36] Based on the first six months of operation, the reserve is estimated to earn about A$18 million per year.[37] (This is a third-party estimate, based on spot energy prices; it is possible that the HPR has contracted to provide power at a lower price, in exchange for a more certain income stream.)
After six months of operation, the Hornsdale Power Reserve was responsible for 55% of frequency control and ancillary services in South Australia.[31] The battery usually arbitrages 30 MW or less, but in May 2019 began charging and discharging at around 80 MW and for longer than usual, increasing wind power production by reducing curtailment.[38][39] FCAS is the main source of revenue.[23][40] When the Heywood interconnector failed for 18 days in January 2020, HPR provided grid support while limiting power prices.[41] This event was the main contributor to Neoen's €30 million ($A46.3 million) operating profit from Australian battery storage in 2020.[20]
In 2022, HPR started providing an estimated 2,000 MWs of inertial response to the grid. Such services usually being provided by coal and gas generators, HPR was the first big battery in the world to provide such services, and particularly useful given South Australia's high renewable penetration.[42]
Benefits for the consumers
By the end of 2018, it was estimated that the Power Reserve had saved A$40 million in costs, mostly in eliminating the need for a fuel-powered 35MW Frequency Control Ancillary Service[43] also known as peaker plants. In 2019, grid costs were reduced by $116 million due to the operation of HPR. Almost all of the savings delivered by the Hornsdale battery came from its role in frequency and ancillary control markets, where HPR reduced costs by 91% from $470/MWh to $40/MWh;[44] while providing a faster response of 100 ms vs 6000 ms with previous Contingency FCAS agreements.[45]As of 2024[update], HPR is the largest battery in Australia with grid-forming abilities.[46]
Controversy
On September 23, 2021, the Australian Energy Regulator sued Neoen SA, saying the French firm's Tesla "Big Battery" in South Australia did not provide backup power during four months in 2019 for which it had received payment.[47] The company was ultimately fined $900,000.[48]
1 2 "Tesla's Giant Battery Farm Ready to Flick the Switch". The Urban Developer. 29 November 2017. Archived from the original on 27 March 2019. Retrieved 30 November 2017. The 100-megawatt battery installation has been built as promised by tech-billionaire Elon Musk within 100 days of the contract being signed back in September
1 2 Parkinson, Giles (12 March 2021). "Neoen aims for big batteries in every state following success of Tesla big battery". RenewEconomy. Archived from the original on 16 March 2021. the Hornsdale battery was the single most profitable asset in Neoen's portfolio across Australia, Europe and the Americas, largely as a result of the key role it played, and the windfall it gained, from holding the South Australia grid together {in early 2020} during a lengthy "islanding" event
1 2 Parkinson, Giles (19 December 2017). "Tesla big battery outsmarts lumbering coal units after Loy Yang trips". RenewEconomy. Retrieved 19 December 2017. But in reality, the response from the Tesla big battery was even quicker than that – in milliseconds – but too fast for the AEMO data to record. Importantly, by the time that the contracted Gladstone coal unit had gotten out of bed and put its socks on so it can inject more into the grid – it is paid to respond in six seconds – the fall in frequency had already been arrested and was being reversed.
↑ Peacock, Bella (26 January 2021). "Big battery announcements could see storage pricing 'cannibalise' itself". pv magazine Australia. Archived from the original on 5 February 2021. [Frequency Control Ancillary Services] FCAS markets are a large driver of revenues for large scale battery assets in the NEM … last calendar year FCAS revenues accounted for more than 96% for Hornsdale Power Reserve (c.f. 83% in CY19)
↑ "Year 2 Technical and Market Impact Case Study"(PDF). Aurecon. HPR is modelled to have reduced the total Contingency FCAS cost by approximately $80M, and the total Regulation FCAS cost by approximately $36M, for a total NEM cost reduction of approximately $116M
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