The Australian Energy Market Commission (AEMC) is an agency of the federal government tasked with governing the rules of the National Electricity Market (NEM), the electricity grid covering the Australian states of Queensland, New South Wales, ACT, Victoria, Tasmania and South Australia. This represents approximately 80% of the Australian energy consumption (AEMC 2017).
The wholesale price of electricity is struck at 30 second increments at the lowest price that will supply the necessary power, often referred to as a ‘merit order’ (see Figure 2). Supply is effectively guaranteed during peak demand (normally the hot days in Australia when air conditioners are all turned on) by allowing the wholesale price to spike, incentivising more expensive sources to come online. Some generation capacity can operate for as little as 10 hours a year and still be profitable (Parkinson 2017).
The primary actors in the electricity grid are (see Figure 3 for more details):
Over the past decade, two phenomena have undermined the efficiency of the NEM, increasing prices to consumers, and in some cases, affecting electricity supply:
Public anger with these increased costs, as well as the precipitous drop in new energy technologies, has the potential to limit further cost increases and wrestle some control from the energy incumbents.
Combining distributed technologies (e.g. solar PV panels and battery storage) with digitalisation can counteract the forces that have driven up prices for consumers and transform of the energy system.
The specific region under analysis is the Lower Mornington Peninsula, in the state of Victoria, Australia. The area is roughly 100km from central Melbourne, and is a popular holiday spot, due to its proximity to the coast.
The electricity demand in this region is made up predominantly of the residential sector. (United Energy 2015). The number of permanent residents in the area stands at 150,000, but can increase by approximately 30% during the peak summer months (Mornington Peninsula Shire 2012).
There is also a high penetration of solar panels in the region, producing a classic ‘duck curve’ to the residual demand in the region. See Figure 5.
In 2014, the local utility, United Energy (UE), concluded that if they did nothing to address the issue over the next 5 years, reliability could be threatened. Under network rules, Utilities such as UE are obligated to put any work expected to pass a threshold of $A5 million to outside tender and consider non-network if it could be shown to reduce demand or utilize embedded generation(AER 2013).
Software company GreenSync proposed such a solution, named the ‘Community Grids Project’ (CGP). A small scale trial was run over the 2016/17 summer period, and will commence in earnest in late 2018.
The following strategies were employed as part of the solution:
The main problem of the case was to prove to policymakers that non-network solutions could be used at a large scale in a way that:
The emergence of the Smart Urban Energy System (SUES) is challenging the assumptions embedded in the traditional energy services layer in the following ways:
|Consumers (except very large ones) cannot generate, store or trade their own energy.||Distributed energy technologies (DETs) have experienced massive cost reductions, making them an option for more consumers.|
|Consumers cannot dynamically control their energy demand.||With DETs and smart management, prosumers can decouple their energy consumption from their actual grid demand.|
|Generation and distribution infrastructure requires large, long term investment.||DETs can be purchased and installed at a very small scale, requiring a shorter investment horizon and less regulatory certainty for the buyer.|
|Consumers want certainty on price.||New intermediaries, such as energy startups, are smartly mitigating energy market fluctuations on behalf of consumers.|
Table 1: SUES challenge to energy market orthodoxy
The first attempt at implementing a SUES in Australia was primarily a top-down initiative, using smart meters to incentivise consumers to reduce consumption at key times of expected stress on the grid, also known as ‘time of use’ pricing. This disregarded the dynamics shaping the energy market, however:
The CGP, by implementing a ‘microgrid’ model, harnessed these dynamics in a way that benefitted the grid and reduced network expenditure. The trial has been a success and will be the solution to provide grid reliability to the Mornington Peninsula region for the next 5 years.
This solution, however, still represents an ‘integrated’ vision of grid management. UE has simply outsourced network reliability for a section of their network to a third party for a period of time. There is minimal transparency of grid performance, and only a narrower group of actors can participate.
GreenSync developed deX, or Distributed Energy Exchange, represents a different vision, a ‘data platform’. It will allow solutions to be provided from a variety of actors, and for policymakers to turn learn what regulatory changes could be most effective.
Examples of the network services that could be provided by deX include:
deX could catalyse a new class of actors in the energy market who will enable the benefits of digitalisation to emerge:
deX has only recently been announced, but has attracted a wide array of industry actors (including regulators and large incumbents) as foundational supporters.
The Australian experience has clearly demonstrated how not to ensure a cost-effective and innovative grid. Generators have used their powerful market position to manipulate wholesale prices, and Utilities have used the vague objective of reliability’ to overspend on capital expenditure..
The emergence of the SUES offers the opportunity for DETs to be absorbed into the grid to help address the needs of the grid more effectively. The CGP has shown that segmenting a monolithic grid and better defining the concept of grid reliability can lead to novel, more cost-effective solutions. deX takes that concept one step further by allowing more grid services to be provided by a new class of actors and business models.
We’re only at the beginning!
Australian Energy Market Commission (AEMC) (2017) “National Electricity Market”. aemc.gov.au. Web. 11 June 2017.
Australian Energy Market Operator (AEMO) (2017) “AEMO Maps”. aemo.com.au. Web. 11 June 2017.
Australian Energy Regulator (AER) (2013) Regulatory investment test for distribution Application Guidelines. Melbourne, VIC, Australia. Pg. 8.
Beránek, J. (2013) “Energetika Po Fukušimě: Německo – Ceny Elektřiny (Část IV.)”. Aktuálně.cz – Víte, co se právě děje. Web. 11 June 2017.
Knupfer, S, Hensley, R, Hertzke, P, Schaufuss, P, Laverty, N Kramer, N. (2017) Electrifying insights: How automakers can drive electrified vehicle sales and profitability. McKinsey & Company, New York City, NY, USA, Pg. 10.
Mornington Peninsula Shire (2012) Strategic Plan 2013–2017. Rosebud, VIC, Australia. Pg. 7.
Origin Energy (2017) “Understanding Your Electricity Bill”. Originenergy.com.au. Web. 11 June 2017.
Parkinson, G. (2017) “AEMO Says Major Market Reform Essential To Cut Energy Prices”. RenewEconomy. Web. 11 June 2017.
Swenson, D. (2016) “The ‘Electrical Grid’ Vs. The ‘Financial Grid’ Comparison!”. Kingdom Economics – The Future Is Now. Web. 11 June 2017.
Trabish, H. (2014) “The ‘Epic Fail’ On Solar’s Doorstep—And How The Grid Can Help”. Utility Dive. Web. 11 June 2017.
United Energy (2015) Final Project Assessment Report – Lower Mornington Peninsula Supply Area. United Energy, Mount Waverley, VIC, Australia. Pg. 6.
Vorrath, S. (2017) ““Watershed” Demand Response, Battery Storage Project Wins Victoria Grant”. RenewEconomy. Web. 11 June 2017.
Featured Image: Alex Proimos from Sydney, Australia
This piece is the original writing of the author(s). The view points in the post is the author’s personal opinions and do not reflect IGLUS/EPFL’s viewpoints. The author(s) is the sole responsible person regarding the accuracy of the information presented in the post and will be liable for any potential copyright infringements.