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Electrical infrastructure is one of the major causes of bushfire in Australia alongside arson and lightning strikes. The two main causes of electrical-infrastructure-initiated fires are asset failure and powerline vegetation interactions. In this paper, we focus on powerline–vegetation interactions that are caused by vegetation falling onto or blowing onto electrical infrastructure. Currently, there is very limited understanding of both the spatio-temporal variability of these events and their causative factors. Bridging this knowledge gap provides an opportunity for electricity utility companies to optimally allocate vegetation management resources and to understand the risk profile presented by vegetation fall-in initiated fires, thereby improving both operational planning and strategic resource allocation. To bridge this knowledge gap, we developed a statistical rare-event modelling and simulation framework based on Endeavour Energy's fire start and incident records from the last 10 years. The modelling framework consists of nested, rare-event-corrected, conditional probability models for vegetation events and consequent ignition events that provide an overall model for vegetation-initiated ignitions. Model performance was tested on an out-of-time test set to determine the predictive utility of the models. Predictive performance was reasonable with test set AUC values of 0.79 and 0.66 for the vegetation event and ignition event models, respectively. The modelling indicates that wind speed and vegetation features are strongly associated with vegetation events, and that Forest Fire Danger Index (FFDI) and soil type are strongly associated with ignition events. The framework can be used by energy utilities to optimize resource allocation and prepare future networks for climate change. [ABSTRACT FROM AUTHOR]

In this paper, we review studies to understand how much households change their electricity consumption when there is a price change. Many studies find residential households have long‐term and short‐run elasticities behaving as economic theory would suggest. Long‐run elasticities range from −0.75 to −0.3, and short‐run elasticities range from −0.47 to −0.026. Household responsiveness seems to increase when paired with technology. The major gaps in research from the empirical economic literature are how low‐income and vulnerable Australian households could be affected by price changes and how Australians respond to within‐day variation in prices. [ABSTRACT FROM AUTHOR]

Synchronous generators are operating for less time than before or being decommissioned in the National Electricity Market (NEM) of Australia, due to the proliferation of asynchronous wind and solar generation. Sub-networks of the NEM will face inertia shortages in the near future. This paper develops a formulation of zonal inertia constrained generator dispatch for power systems with a diversified generator portfolio including synchronous generators, synchronous condensers, inverter-interfaced generators and energy storages. Zonal inertia constraints are formulated in unit commitment and optimal power flow to limit the rate of change of frequency (RoCoF) in the event of network separation. Load frequency relief is also considered to reduce the ramp rate requirement of primary reserve. The proposed formulation can reduce the average cost of primary reserve and maintain zonal inertia adequacy to constrain RoCoF in case of the trip of the interconnector(s). [ABSTRACT FROM AUTHOR]

The objective of this paper is to explain the relationship between high frequency electricity demand, intra-day temperature variation and time. Using the Generalised Additive Model (GAM) framework we link high frequency (5-minute) aggregate electricity demand in Australia to the time of the day, time of the year and intra-day temperature. We document a strong relationship between high frequency electricity demand and intra-day temperature. We show a superior model fit when using Daylight Saving Time (DST), or clock time, instead of the standard (solar) time. We introduce the time weighted temperature model that captures instantaneous electricity demand sensitivity to temperature as a function of the human daily activity cycle, by assigning different temperature signal weighting based on the DST time. The results on DST and time weighted temperature modelling are novel in the literature and are important innovations in high frequency electricity demand forecasting. [ABSTRACT FROM AUTHOR]

Emission trading is widely considered to be the most effective policy to minimize the overall costs for CO2 abatement. However, the political feasibility of an emission trading scheme may crucially depend on the free initial allocation of emission permits to carbon-intensive industries in order to offset the reduction in profits.This paper aims to analyze these potential profit impacts and the possible compensation to affected generation compaflies through modeling the Australian National Electricity Market under a potential emission trading scheme. Historical emissionbased and historical generation-based allocation approaches are used in this paper to calculate and compare the percentages of carbon permits that should be freely allocated. Two carbon permit price scenarios are -used to analyze the sensitivity of the optimal percentage of free allocation to carbon permit price. [ABSTRACT FROM AUTHOR]

Australia offers an interesting case study of climate policy effectiveness as Australia has 'tried' a wide range of policies to mixed effect. Given that more than half of Australia's greenhouse gas emissions typically come from stationary energy generation, most climate policy in Australia has focussed on electricity sector reform, particularly the uptake of variable renewable energy and the decrease of thermal power generation. Electricity supply in Australia has undergone substantial change over recent years, substantially due to these policies, and needs to continue changing in the future to meet climate change mitigation targets and ensure stable, cost-effective electricity supply. This paper is therefore written from the perspective of an electricity planner and seeks to learn from the experiences of climate policies tried over recent decades. We start by reviewing the history of Australian energy policy and a description of how the Australian electricity network is structured to operate. We examine the theory and effects of different policies tried, which range from renewable energy targets, carbon pricing schemes, subsidies for renewable energy and research and development initiatives. We make three key observations from the case analysis: (1) that there has been substantial expense and effort effectively wasted through duplicate effects of different policy mechanisms by both federal and state governments; (2) as various mechanisms enable variable renewable energy generation to increase, the market becomes distorted, increasing total system costs and decreasing system robustness and resilience; and (3) the narrowed focus of climate policy mechanisms on certain variable renewables, such as solar photovoltaic and wind generation, omitted the opportunity for uptake of scale-able low carbon, firm generation options, like nuclear power and carbon capture and storage., (Copyright © 2020 Elsevier Ltd. All rights reserved.)

This paper analyzes the interplay of transmission and storage investments in a multistage game that we translate into a bilevel market model. In particular, on the first level we assume that a transmission system operator chooses optimal line investments and a corresponding optimal network fee. On the second level we model competitive firms that trade energy on a zonal market with limited transmission capacities and decide on their optimal storage facility investments. To the best of our knowledge, we are the first to analyze interdependent transmission and storage facility investments in a zonal market environment that accounts for the described hierarchical decision structure. As a first best benchmark, we also present an integrated, single-level problem that may be interpreted as a long-run nodal pricing model. Our numerical results show that adequate storage facility investments of firms may in general have the potential to reduce the amount of line investments of the transmission system operator. However, our bilevel zonal pricing model may yield inefficient investments in storages, which may be accompanied by suboptimal network facility extensions as compared to the nodal pricing benchmark. In this context, the chosen zonal configuration of the network will highly influence the equilibrium investment outcomes including the size and location of the newly invested facilities. As zonal pricing is used for instance in Australia or Europe, our models may be seen as valuable tools for evaluating different regulatory policy options in the context of long-run investments in storage and network facilities. [ABSTRACT FROM AUTHOR]

This paper examines the potential role for fuel substitution in electricity production in reducing carbon dioxide emissions over a ten-year time horizon. This is achieved by adding fuel substitution to output changes resulting from demand responses arising from a tax on carbon dioxide emissions. A time profile of adjustments is developed. The tax required for Australia to meet a 20 per cent reduction in emissions from 1993 levels is calculated and effects on inequality and social welfare are examined. The paper also examines the potential effect of a subsidy towards the use of low- emission fuels, financed from the carbon tax. A subsidy produces an improvement in emissions abatement and a lower tax required to reach the emissions target. [ABSTRACT FROM AUTHOR]

• A new energy-as-a-service business model for aggregators of prosumers. • A new techno-economic simulation framework to compute business model benefits. • The new business model increases the average profitability of the aggregator by 438%. • The new business model provides free electricity to prosumers. Traditional retail business models price electricity using volumetric tariffs, which charge customers for the unit of energy consumed. These tariffs were designed for passive consumers with low flexibility. In this paper, we argue that these volumetric tariffs are unsuitable for prosumers with high flexibility since they are unable to adequately value the flexibility of their distributed energy resources in multiple electricity markets. This reduces the interest of prosumers participating in aggregators' business models. To address this issue, we propose a new business model for aggregators of prosumers, based on the concept of energy-as-a-service. In this business model, prosumers pay a monthly fee for aggregators to represent and optimize them in multiple wholesale electricity markets, including in energy and ancillary service markets. The monthly fee is computed by a new techno-economic simulation framework proposed in this paper, which can also be used to estimate the profitability of the new business model from the perspectives of both the aggregator and prosumers. Our experiments on a portfolio of real prosumers from Australia show that the new business model maximizes the economic benefits of both the aggregator and prosumers by increasing the average profit of the aggregator by 438% and reducing the average electricity cost of prosumers from $583/year to $0 when compared to two of the most common retail business models available in the Australian market. In other words, the economic benefit for prosumers is free electricity. In addition to this benefit, the new business model also provides simplicity and predictability to prosumers, as they are offered a guaranteed outcome before providing the services. [ABSTRACT FROM AUTHOR]

The article presents abstracts related to electricity including "Estimator-based sliding mode control strategy design," by J. D. Lee, J. F. Lin, and A. J. Li, "A discrete multi-objective particle swarm optimization dynamic self-regulating energy management scheme for smart grid applications," by A. A. A. Elgammal and A. M. Sharaf, "Upgrading and uprating of hydro generators: An Australian perspective," by M. M. Znidarich .

In this brief update on analysing the economic costs associated with carbon policy uncertainty, we outline the public policy processes commenced by the Commonwealth Government following the publication of Nelson et al. (2010). We also summarise the research completed by other economists testing the hypothesis that there are material economic costs associated with ongoing carbon policy uncertainty. Independent studies by Frontier Economics (2010), Deloitte (2011) and Sinclair Knight Merz (2011) all conclude that climate change policy uncertainty will result in sub-optimal capital investment within the electricity sector. In turn, this sub-optimal investment will manifest itself in unnecessary increases in electricity prices. [ABSTRACT FROM AUTHOR]

This paper investigates the intraday price volatility process in four Australian wholesale electricity markets; namely New South Wales, Queensland, South Australia and Victoria. The data set consists of half-hourly electricity prices and demand volumes over the period January 1, 2002 to June 1, 2003. A range of processes including GARCH, RiskMetrics, normal Asymmetric Power ARCH or APARCH, Student APARCH and skewed Student APARCH are used to model the time-varying variance in prices and the inclusion of news arrival as proxied by the contemporaneous volume of demand, time-of-day, day-of-week and month-of-year effects as exogenous explanatory variables. The skewed Student APARCH model, which takes account of right skewed and fat tailed characteristics, produces the best results in all four markets. The results indicate significant innovation (ARCH effects) and volatility (GARCH effects) spillovers in The conditional standard deviation equation, even with market and calendar effects included. Intraday prices also exhibit significant asymmetric responses of volatility to the flow of information. [ABSTRACT FROM AUTHOR]

This paper investigates a comparative study for practical optimal sizing of rooftop solar photovoltaic (PV) and battery energy storage systems (BESSs) for grid-connected houses (GCHs) by considering flat and time-of-use (TOU) electricity rate options. Two system configurations, PV only and PV-BESS, were optimally sized by minimizing the net present cost of electricity for four options of electricity rates. A practical model was developed by considering grid constraints, daily supply of charge of electricity, salvation value and degradation of PV and BESS, actual annual data of load and solar, and current market price of components. A rule-based energy management system was examined for GCHs to control the power flow among PV, BESS, load, and grid. Various sensitivity analyses are presented to examine the impacts of grid constraint and electricity rates on the cost of electricity and the sizes of the components. Although the capacity optimization model is generally developed for any case study, a grid-connected house in Australia is considered as the case system in this paper. It is found that the TOU-Flat option for the PV-BESS configuration achieved the lowest NPC compared to other configuration and options. The optimal capacities of rooftop PV and BESS were obtained as 9 kW and 6 kWh, respectively, for the PV-BESS configuration with TOU-Flat according to two performance metrices: net present cost and cost of electricity. [ABSTRACT FROM AUTHOR]

Environmental concerns often preclude establishment of a new hydro generating plant. Hydro generators are still the main source of renewable energy that is available on a large scale. They are eminently suitable for peaking duty, which often provides attractive returns to the power utilities in privatised electricity markets. Many power utilities therefore resort to upgrading and uprating their ageing generating plants. The hydro generators designed and built around the middle of last century were generously sized by today's standards, and generally permit significant increases in machine output, when contemporary material technology and engineering designs are utilised. Large electrical machines were never manufactured in Australia, and thus locally based practical engineering design experience was never evolved. Over the last 30 years the author has researched and developed a unique domestically based engineering design knowledge and expertise required to test, analyse, redesign and upgrade/uprate existing Australian hydro generators. This paper outlines the approach and general engineering methodology the author has used to upgrade and uprate numerous hydro generators. The hydro generator life span and life cycle are considered, and the scope of possible upgrading and uprating is outlined. The methodology for hydro generator uprating is described, including generator data collection, pre-uprate generator performance testing, electromagnetic and performance analysis, and contents of the final design output. [ABSTRACT FROM AUTHOR]

Short-term load forecasting is an essential instrument in power system planning, operation, and control. Many operating decisions are based on load forecasts, such as dispatch scheduling of generating capacity, reliability analysis, and maintenance planning for the generators. Overestimation of electricity demand will cause a conservative operation, which leads to the start-up of too many units or excessive energy purchase, thereby supplying an unnecessary level of reserve. On the other hand, underestimation may result in a risky operation, with insufficient preparation of spinning reserve, causing the system to operate in a vulnerable region to the disturbance. [ABSTRACT FROM PUBLISHER]

This paper develops new practical rule-based energy management systems (EMSs) for typical grid-connected houses with solar photovoltaic (PV) and battery by considering different rates for purchasing and selling electricity. The EMSs are developed to supply the household's loads and reduce operating costs of the system based on different options of flat and time-of-use (ToU) rates for buying and selling electricity prices. Four different options are evaluated and compared in this study: (1) Flat-Flat, (2) ToU-Flat, (3) Flat-ToU, and (4) ToU-ToU. The operation cost is calculated based on the electricity exchange with the main grid, the equivalent cost of PV generation, as well as the degradation cost of battery storage. The operation of the grid-connected house with rooftop solar PV and battery is evaluated for a sunny week in summer and a cloudy week in winter to investigate the proper performance for high and low generations of PV. While the developed rule-based EMS are generic and can be applied for any case studies, a grid-connected house in Australia is examined. For this purpose, real data of solar radiation, air temperature, electricity consumption, and electricity rates are used. It is found that the ToU-Flat option has the lowest operating cost for the customers. [ABSTRACT FROM AUTHOR]

Electricity load forecasting plays an essential role in improving the management efficiency of power generation systems. A large number of load forecasting models aiming at promoting the forecasting effectiveness have been put forward in the past. However, many traditional models have no consideration for the significance of data preprocessing and the constraints of individual forecasting models. Moreover, most of them only focus on the forecasting accuracy but ignore the forecasting stability, resulting in nonoptimal performance in practical applications. This paper presents a novel hybrid model that combines an advanced data preprocessing strategy, a deep neural network, and an avant-garde multi-objective optimization algorithm, overcoming the defects of traditional models and thus improving the forecasting performance effectively. In order to evaluate the validity of the proposed hybrid model, the electricity load data sampled in 30-min intervals from Queensland, Australia are used as a case to study. The experiments show that the new proposed model is obviously superior to all other traditional models. Furthermore, it provides an effective technical forecasting means for smart grid management. [ABSTRACT FROM AUTHOR]

This paper examines the cost-effectiveness of subsidies (feed-in tariffs and renewable energy credits) paid for by electricity consumers to support the uptake of roof top photovoltaic (PV) systems by households in Australia. We estimate annual payback periods, and then regress these against the actual uptake of household PV and associated emission reductions, creating a relationship not apparent in other research. Sensitivity analysis reveals that the declining cost of PV panels had most impact on PV uptake followed by feed-in tariffs, renewable energy credits and the increasing cost of household electricity tariffs. Our modelling shows that feed-in tariffs were higher than necessary to achieve the resultant levels of PV uptake and that the low cost of PV panels and comparatively high electricity tariffs are likely to result in a continuing strong uptake of household PV in Australia. Our modelling shows that subsidies peaked in 2011 and 2012, with payback periods of three to four years, having since increased to five to six years. Emission reduction costs are expected to reduce from over AU$200 per t CO 2 e in 2013 to between AU$65 and AU$100 per t CO 2 e in 2020. Household PV reduced Australia’s emissions by 3.7 million t CO 2 e in 2013 (1.7% of Australia’s total emissions) and is expected to reach eight million tonnes (3.7% of Australia’s total emissions) by 2020. [ABSTRACT FROM AUTHOR]

We report the upper and lower bounds for the levelized cost of high-temperature industrial process heat, supplied from electricity generated with solar-photovoltaic (PV) and wind turbines in combination with either thermal or electric battery storage using hourly typical meteorological year (TMY) data, in systems sized to supply between 80% and 100% of continuous thermal demand at a site in the northern part of Western Australia. The system is chosen to supply high-temperature air as the heat transfer media at temperatures of 1000 °C, which is a typical temperature for an alumina or a lime calcination plant. A simplified model of the electrical energy plant has been developed using performance characteristics of real PV and wind systems and TMY data of renewable energy resources. This was used to simulate a large sample of possible system configurations and find the optimal combination of the renewable resources and storage systems, sized to provide renewable shares (RES) of between 80% and 100% of the yearly demand. This allowed the upper and lower bounds to be determined for the cost of heat based on two scenarios in which the excess energy is either dumped (upper bound) or exported to the electricity grid (lower bound) at the average generating cost. The lower bound of the levelized cost of energy ( L C O E L ), which occurs for the system employing thermal storage, was estimated to range from USD 10/GJ to USD 24/GJ for RES from 80 to 100%. The corresponding upper bound (L C O E U ), also estimated for the system using thermal storage, are between USD 16/GJ and USD 31/GJ, for RES between 80% and 100%. The utilization of electric battery storage instead of thermal storage was found to increase the LCOE values by a factor of two to four depending on the share of renewable energy. Compared with current Australian natural gas cost, none of the systems assessed configurations is economical without either a cost for CO2 emissions or a premium for low-carbon products. The estimated cost for CO2 emission that is needed to reach parity with current natural gas prices in Australia is also presented. [ABSTRACT FROM AUTHOR]

• Bottom-up estimation tool to develop electric public transport (EPT) charging loads. • Uses GTFS public data and can be scaled to hundreds of cities/states globally. • EPT could add 17% to critical peak demand on some distribution zone substations. Battery electrified public transit (BEPT), including buses and passenger ferries, is a promising solution to transport-related climate emissions and urban air pollution, but introduces potentially challenging large, coincident demand in the low-voltage distribution network. This paper presents a tool for estimating the energy and charging demand of electrified public transit using public data that is available in over 150 cities/states globally and demonstrates it in two case studies. The tool applies heuristic vehicle scheduling to existing public General Transit Feed Specification data to model the charging profiles and electricity consumption of BEPT for various charging regimes across different geographical scales. For the case study of New South Wales, Australia, the impacts of BEPT are most significant at the low-voltage network, where adding a battery-electric bus depot was found to increase the annual critical peak demand at the local zone substation in Summer by up to 17% while exacerbating demand during the daily evening peak period by 20–30%. Across the entire state of NSW, a full transition to BEPT increases annual electricity consumption by 1.28–1.34% and peak daily demand by 1–3%. [ABSTRACT FROM AUTHOR]

Abstract: Integration of distributed generation (DG) in a distribution network may introduce adverse effects including control interaction, oscillatory transients and operational conflicts. This paper investigates the operation of multiple voltage regulators such as on-load tap changer (OLTC) and step voltage regulator (SVR), and DG in a medium voltage distribution feeder. Investigations have been carried out using time domain simulation studies conducted using MATLAB-SimPowerSystems. The results are reported for a case study involving radial distribution feeder, derived from New South Wales (NSW) electricity distribution network in Australia. [Copyright &y& Elsevier]

The power industry has been grappling with regulatory uncertainty in relation to carbon since late 2004 when Australian state governments committed to the introduction of an emissions trading scheme. This article estimates the additional cost to electricity users associated with the sub-optimal introduction of new power generating capacity given regulatory delays. We find the costs to be significant; under a business-as-usual electricity demand growth scenario, prices in 2020 would be about $8.60/MWh higher than necessary. We also find that costs to consumers are lower where complementary policies are introduced to encourage energy efficiency and renewable energy. [ABSTRACT FROM AUTHOR]

Australia's national electricity market (NEM) is national in name only. It is eight years since the NEM commenced and the objective of a fully competitive market has not been reached. The NEM's structural characteristics, shaped strongly although not exclusively by its evolving regulatory regime, have created the exact antithesis. This paper examines the NEM's key structural characteristics, the consequential pricing and investment outcomes and the conundrums posed for governments and regulators elucidating the reasons why a fully competitive NEM--beyond an increased number of buyers and sellers, and choice of supplier for all consumers--can not be attained without substantial changes. [ABSTRACT FROM AUTHOR]

The pricing of access to electricity transmission networks in Australia is currently under review. Several options have been proposed including those based on nodal pricing and the assignment of transmission rights contracts. As most of the marginal costs of transmission are recovered through wholesale electricity prices we focus on the key issue of regulation and investment incentives. We find that current options are unlikely to be adequate in terms of encouraging socially optimal levels and timing of new transmission investment. As an alternative, we propose a regulatory scheme, based on a related idea by Sappington and Sibley that can overcome this problem. Our scheme can potentially generate first best results and is readily applicable given the current institutional structure of electricity markets in Australia. [ABSTRACT FROM AUTHOR]

This article examines the impact of the elimination of x-inefficiency in the Australian electricity supply industry using a computable genera! equilibrium (CGE) model of the Australian economy. Data envelopment analysis and a stochastic production frontier model are applied to measure x-inefficiency in the electricity industry. The potential increase in total factor productivity resulting from microeconomic reform is introduced into the CGE model as a factor-augmenting technological change. The model is used to measure the macroeconomic effects of microeconomic reform of the electricity industry. The Monash model is also used to replicate the results of earlier studies by the Industry Commission (1995) and Quiggin (1997) and thereby to provide a basis for comparing the three sets of results. The results of the current study imply that the impact of microeconomic reform on economic growth could well be significant if only a small proportion of the benefits were to be reflected in terms of an increase in aggregate employment. [ABSTRACT FROM AUTHOR]

• The impacts of COVID lockdown on six aged care communities' energy and peak demand are studied. • The lockdown period was compared with the same period of similar temperature in previous years. • The impacts of COVID lockdown varied enormously in different climate regions. • Effectiveness and limitations of existing energy KPIs are discussed. In late March to April 2020 residential aged care facilities (RAC) in Australia were under COVID-19 lockdown. This paper explores whether the resultant restrictions on entry and exit and elimination of site group activities within RACs impacted on the total electricity use, peak demand and electrical load profiles. Six RACs in four different climate zones are analysed, comparing historical electricity load and demand profiles with the lockdown period. The facilities in warm regions showed largest reductions in energy use and peak demands. There was a peak demand timing shift in temperate regions and hot regions' changes were negligible for energy use or peak demands. This study revealed the limitations of using aggregate data as the key performance indicator (KPI) – energy use per bed. Also, KPIs in relation to cooling degree days (or total cooling and heating degree days) have been examined and are not recommended for temperate regions or temperate seasons. The potential CO 2 emission reduction from onsite renewable generation is quantified. Further research is to investigate energy use changes at circuit levels under lockdowns, and develop more nuanced KPIs that include the rate of energy use and the timing of that use. [ABSTRACT FROM AUTHOR]

The purpose of this paper is to provide a consideration of the role of battery energy storage in enhancing electricity grid stability at a time of increased use of non-hydro renewable generation sources, focusing on the Australian case. Besides the creation of a strategic reserve one measure that might reduce this instability that have being increasingly attracted much attention by both the operators of power systems and electricity distribution networks is the use of battery energy storage. Together, the multitude of regulatory and advisory bodies operating in and around the National Electricity Market of Australia (NEM), and the diverse and sometimes contrary opinions as to the best underlying foundational architecture for the NEM, overlaid by ongoing disagreement at the government policy level, point to continuing uncertainty and difficulties for an Australian electricity system in a state of transition. [ABSTRACT FROM AUTHOR]

This paper examines security of supply concerns in an Australian electricity market under transition and considers potential policy pathways to address them. It details the current state of Australia's electricity industry, considers the extent to which supply security in the electricity sector may be considered a public good, and examines the features likely to impact on the efficacy of current and potential future market designs. [ABSTRACT FROM AUTHOR]

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In theory, well designed electricity markets should deliver an efficient mix of technologies at least-cost. But energy market theories and energy market modelling are based upon equilibrium analysis and in practice electricity markets can be off-equilibrium for extended periods. Near-term spot and forward contract prices can and do fall well below, or substantially exceed, relevant entry cost benchmarks and associated long run equilibrium prices. However, given sufficient time higher prices, on average or during certain periods, create incentives for new entrant plant which in turn has the effect of capping longer-dated average spot price expectations at the estimated cost of the relevant new entrant technologies. In this article, we trace generalised new entrant benchmarks and their relationship to spot price outcomes in Australia's National Electricity Market over the 20-year period to 2018; from coal, to gas and more recently to variable renewables plus firming, notionally provided by--or shadow priced at--the carrying cost of an Open Cycle Gas Turbine. This latest entry benchmark relies implicitly, but critically, on the gains from exchange in organised spot markets, using existing spare capacity. As aging coal plant exit, gains from exchange may gradually diminish with 'notional firming' increasingly and necessarily being met by physical firming. At this point, the benchmark must once again move to a new technology set... [ABSTRACT FROM AUTHOR]

It is claimed that 'Big Data' could help cities become 'smart', utilise resources more efficiently, and improve inhabitants' quality of life. Metered consumption data of electricity, gas and water are collected and stored for each household in Australia and provide a valuable source of information for researchers hoping to understand the patterns of consumption and improve resource utilisation. This work tests the assumption that these datasets are sufficiently 'clean' to allow interrogation and details the common errors encountered. An inspection of 1-7 years of meter readings of electricity, gas and water for ~60,000 households in Canberra, Australia as well as all datasets of the local government's energy and water efficiency programs, found this not to be the case. Common errors found include: missing data, biases in erroneous data, errors generated by the data custodians, duplicate entries, the effect of different custodian objectives and of poor data constraints (free flowing text). [ABSTRACT FROM AUTHOR]

Realistic models of occupant behaviour in relation to air-conditioner (a/c) use are fundamentally important for developing accurate building energy simulation tools. In Australia and elsewhere, such simulation tools are inextricably bound both in legislation and in the design of new technology, electricity infrastructure and regulatory schemes. An increasing number of studies in the literature confirm just how important occupants are in determining overall energy consumption, but obtaining the data on which to build behaviour models is a non-trivial task. Here data is presented on air-conditioner usage derived from three different types of case study analyses. These are: (i) use of aggregate energy consumption data coupled with weather, demographic and building statistics across Australia to estimate key predictors of energy use at the aggregate level; (ii) use of survey data to determine characteristic a/c switch on/off behaviours and usage frequencies; and (iii) use of detailed household level sub-circuit monitoring from 140 households to determine a/c switch on/off probabilities and their dependence on different building and occupant parameters. These case studies are used to assess the difficulties associated with translation of different forms of individual, aggregate and survey based information into a/c behaviour simulation models. Finally a method of linking the data gathering methodologies with the model development is suggested. This method would combine whole-of-house "smart"-meter data measurements with linked targeted occupant surveying. [ABSTRACT FROM AUTHOR]

The electricity supply industry has historically offered a homogenous good supplied via economically regulated transmission and distribution networks. Competition was introduced into the contestable generation and retail supply chain components as part of the 1990s Hilmer reform process. After a century of incremental technological developments, the industry is now being transformed by new distributed energy technologies and a global focus on reducing anthropogenic greenhouse gas emissions. Policy-makers did not anticipate these changes. A number of key reforms are likely to be required. These include: assessing whether the return on capital provided to network operators is appropriate given changing economic conditions; determining the role of competition in the provision of 'behind the meter' energy services; and integration of climate change policy with wholesale energy market design. [ABSTRACT FROM AUTHOR]

Proposals to reform default 'flat-rate' electricity tariffs are rarely met with enthusiasm by consumer groups or policymakers because they produce winners and losers. Proposals to initiate more cost-reflective time-of-use rates will be met with cautious interest if the basis of customer participation is 'opt-in'. Using the smart meter data of 160,000 residential customers from the Victorian region of Australia's National Electricity Market, our tariff model reveals that households in financial hardship are the most adversely affected from existing flat-rate structures. Even after network tariff rebalancing, Hardship and Concession & Pensioner Households are, on average, beneficiaries of more cost-reflective tariff structures once Demand Response is accounted for. [ABSTRACT FROM AUTHOR]

Australia has long been the beneficiary of low, stable power prices. A decade-long state of oversupply underpinned this result and while plant capital costs had been rising, the cost of capital had been declining. These offsetting effects locked the wholesale market into an average cost of $35–$40/MWh. However, from 2007, a simultaneous and sharp rise in new entrant plant capital costs and the cost of capital occurred. The combined effects crept up on the industry while it was in a state of oversupply. This ‘entry cost shock’ disrupted a 7 year long equilibrium price, with average power system cost rising to $60/MWh. [ABSTRACT FROM AUTHOR]

Australia's National Electricity Market (NEM) has been a beacon for governments around the world considering power industry reform. However, while the energy-only NEM has served Australia well since 1998, deep structural supply-side faults exist. Competitive energy-only markets do not have a stable equilibrium solution unless reliability constraints are violated, market power is exercised, or scarcity pricing operates unabated. But the political economy of electricity means none of this is likely. This research finds that by reducing the NEM price cap and introducing a ‘capacity payments pool’, a tractable and politically acceptable equilibrium can be established to facilitate timely plant entry. [ABSTRACT FROM AUTHOR]

Describes the evolution of physical market pricing models toward standardized electricity market design (SMD) with references to the market developments in New Zealand and Australia. Overview of market evolution; SMD functions essential for a robust and competitive market; Stages in the evolution of transmission right allocation models.

Questions whether it is cheaper for households in Australia to use electricity or gas for space heating, water heating and cooking. Claims that gas appliances are technically less efficient than electrical appliances; How reference to a MJ basis can make gas cheaper that electricity; Utilization of an alternative perspective based on econometric methods to determine which is cheaper, gas or electricity.

To achieve the Paris Agreement's long-term temperature goal, current energy systems must be transformed. Australia represents an interesting case for energy system transformation modeling: with a power system dominated by fossil fuels and, specifically, with a heavy coal component, there is at the same time a vast potential for expansion and use of renewables. We used the multi-sectoral Australian Energy Modeling System (AUSeMOSYS) to perform an integrated analysis of implications for the electricity, transport, and selected industry sectors to the mid-century. The state-level resolution allows representation of regional discrepancies in renewable supply and the quantification of inter-regional grid extensions necessary for the physical integration of variable renewables. We investigated the impacts of different CO2 budgets and selected key factors on energy system transformation. Results indicate that coal-fired generation has to be phased out completely by 2030 and a fully renewable electricity supply achieved in the 2030s according to the cost-optimal pathway implied by the 1.5 °C Paris Agreement-compatible carbon budget. Wind and solar PV can play a dominant role in decarbonizing Australia's energy system with continuous growth of demand due to the strong electrification of linked energy sectors. [ABSTRACT FROM AUTHOR]