A long overdue reset to the tariff reform agenda promises better outcomes for energy consumers. Plus a new report finds that retailers really do charge residential customers more than business.
Wholesale energy prices are through the roof and impacting everyone's bills.
This article explains the market operations and pricing mechanisms that set wholesale spot prices for the Australian National Electricity Market (NEM).
We keep hearing that wholesale prices are pushing up the prices we're charged in our retail bills. That's an easy enough concept to understand, but let's look at how those wholesale prices actually get set.
What's the NEM?
The National Electricity Market (NEM) is the power system and associated markets that connect each NEM region - QLD, NSW, ACT, VIC, SA and TAS.
WA and NT run their own independent 'island' electricity distribution networks and are not part of the NEM.
Each NEM region has its own spot price for electricity, except for ACT which is considered part of NSW.
Major network infrastructure of the NEM.
The NEM is an energy-only market. This means that the energy generators – coal-fired power stations, wind farms, gas power stations, etc – only ever get paid by generating and dispatching electricity, so the owners of those generators bear all the costs and financial risks in building and maintaining those generators in the expectation that they'll be able to sell (dispatch) electricity into the NEM.
This structure differs from a capacity market, which exists in Western Australia and in some overseas markets, where generators are paid not only for the energy they generate and dispatch but also for maintaining a guaranteed level of stand-by generation capacity that can be accessed if needed.
How the NEM is managed
Electricity is an unusual commodity because it cannot be stored, at least not at a meaningful scale proportional to overall demand. This means that electricity generation must always be matched with electricity demand in real time.
There is about 65,000 MW of total aggregate generation capacity in the NEM. Consumer demand for electricity varies throughout each day and fluctuates seasonally, so only a subset of this capacity is required at any given time.
However, the aggregate generation capacity must always be larger than the actual demand to accommodate any spikes in demand and to support a buffer for downtime and outages of individual generators. Having too small a margin between anticipated peak demand and maximum aggregate generation capacity increases the risk of power outages.
NEM aggregate generation capacity & demand, MW
The Australian Energy Market Operator (AEMO) manages the operations of the NEM to deliver the most cost-efficient combination of generation and storage required to meet consumer demand for electricity at any given time. AEMO's core activities include:
Dispatch - running an auction process to determine which generators will produce power for each 5-minute 'dispatch period'
Collection of payments from energy retailers for the power consumed by their customers
Facilitating payments to generators for the power they produce and dispatch
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Note that AEMO is only responsible for payment collections from the retailers. It is not responsible for collecting payments from the end-consumers of electricity. Energy retailers perform this crucial role on behalf of the entire energy economy and must absorb the revenue collection risk and the price variability for the commodity they sell.
The dispatch process is the most complicated and interesting part of the NEM operations. AEMO manages this through an auction where generators bid in five-minute windows for the right to supply energy to the NEM at a specified price per mWh. AEMO will choose the cheapest combination of generators required to satisfy the real-time demand across the NEM.
Generator bids
Each individual electricity generator has unique characteristics for the cost and availability of the power it produces. Considering these factors, each generator places bids to the AEMO daily, offering to supply the market with specified amounts of electricity for set time periods at specified prices.
Some generators may offer electricity at negative prices because it costs them more to ramp down and turn off their generator than it does to accept negative prices for continuing production.
Prices can range between the market floor price, currently -$1000/MWh, to the market cap price, currently $15,500/MWh.
The prices bid by each generator will differ based on:
Input costs of fuel for the generator - eg coal or gas prices
Running costs and overheads for the generator
The cost of turning off. Some generators will offer electricity at negative prices because it costs them more to ramp down and turn off their generator than it does to accept negative prices for continuing production.
Portfolio positions, such as the level of consumer load. 'Vertically integrated' generators will also run their own retail operations and will operate their generation assets to meet the energy consumption of their own customers.
Generators that are more expensive to run will typically offer generation at higher prices.
Generators that do not require fuel inputs (such as solar, wind or hydro generators) may bid at lower prices to maximise the likelihood of being consistently dispatched.
The Market operator collates the prices offered by each generator and 'dispatches' the lowest-cost combination of generator volume and price bids required to meet the forecast demand for each 5-minute dispatch period.
This approach to choosing the lowest-cost combination of generation sources is known as merit order pricing.
Merit Order pricing
Merit order is used to determine the order in which energy sources are dispatched to the grid to meet demand, with the lowest-cost sources dispatched first.
The NEM operates with a 5-minute dispatch price window, and the 5-minute dispatch prices are averaged into 30-minute blocks to determine the wholesale market 'spot' price.
Every generator that is dispatched in that 30-minute window will be paid the same spot price per MWh for the energy they dispatch, regardless of the price they bid.
In this simplified example provided by AEMC, we can see how electricity is dispatched and how prices change over a 30-minute settlement period.
Point A : To supply energy at 4:05 PM, generators 1 and 2 are dispatched to their full bid capacity, and generator 3 is partially dispatched. The price is $40 per MWh which was the price bid by generator 3. Generators 1 and 2 will have placed bids lower than that, but the price for each 5-minute dispatch period is set by the highest bidder dispatched
Point B : Demand has increased at 4:10. Generator 3 is now fully dispatched, and generator 4 is partially dispatched. The price increases to the generator 4 bid price of $80 for MWh for this dispatch period.
Point C: demand has increased again at 4:15, and generator 4 is dispatched to a higher level than the previous dispatch period, but still not to the full extent of its bidded capacity. The price remains at $80 per MWh.
Point D: at 4:20 PM demand has again increased, requiring dispatch of some of generator 5 bidded capacity to meet it. The dispatch price is now $100 per MWh, set by the bid price of generator 5
Point E: at 4:25, demand has again increased, requiring more of the capacity of generator 5 to be dispatched. The price remains the same at $100 per MWh
Point F: at 4:30 PM, demand has fallen. Generator 5 is no longer required, and generator 4 is only partially dispatched. The dispatch price falls back to $80 per MWh.
Over this 30-minute settlement period, the dispatch price has varied between $40 and 100 per MWh over 6 dispatch periods. These dispatch prices are then averaged to determine the spot price for the settlement period.
The spot price for this 30-minute period is ($40 +$80 + $80 +$100 + $100 + $80)/6 = $80 per MWh.
The spot price sets what will actually be paid to all the generators dispatched during this period, regardless of what they bid.
Therefore, the spot price also sets what the energy retailers must pay the generators for the energy that their customers consumed during this settlement period.
Spot prices can be very volatile, with extreme fluctuation in pricing, which means that retailers must manage the risk of collecting payments. No matter how the spot price varies, retailers are absolutely on the hook to pay the relevant spot price to the generators for the consumption of their customers - in the second half of 2022 the Australian wholesale energy market saw unprecedented wholesale price shocks, which drove ten retailers into receivership.
Merit order ensures that the grid is supplied with the lowest-cost energy sources available. This keeps energy prices as low as possible for consumers and encourages the use of renewable energy sources, which are typically cheaper than fossil fuels.
Regions and interconnectors
The NEM operates in five regions - South Australia, Melbourne, Tasmania, New South Wales, and Queensland - with interconnectors (transmission links) that join the regions and regional reference nodes (RRNs) at the largest load centre of each region.
NEM Interconnectors and RRNs
Spot prices are calculated at each regional reference node. The spot price at a regional reference node can be set by generation within that region or in another region.
Electricity moves through interconnectors that deliver energy from lower-price regions to higher-price regions. This can equalise prices between regions if the interconnect capacity is sufficient. Spot prices will separate if the interconnect reaches capacity before the price equalises.
Interconnectors are a partial substitute for local generation in a region to the extent they enable the import of electricity, which can mitigate the need for local building of generation capacity in a region.
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