Introduction
This annotated bibliography reviews scholarship and institutional analysis on the barriers to renewable energy investment in Australia’s National Electricity Market. The sources are grouped into market design and regulatory barriers, grid and technical constraints, and finance, social licence and investment risk, reflecting the interacting obstacles that shape the pace of the energy transition. Each entry summarises the source, appraises its methodology and credibility, and explains its relevance to understanding why private capital does not always flow to renewable generation as quickly as decarbonisation targets require.
Market Design and Regulatory Barriers
Australian Energy Market Operator 2022, Integrated system plan for the National Electricity Market, AEMO, Melbourne.
The Integrated System Plan is the operator’s roadmap for the transmission and generation investment needed to move the National Electricity Market toward a low-emissions future. It models several scenarios and identifies the transmission projects and renewable energy zones required under each. Its authority derives from the operator’s central role and its access to detailed system data, and the scenario method is transparent and widely scrutinised. As a planning document it embeds contestable assumptions about demand, technology cost and policy, and it is optimistic about delivery timelines that later sources question. It is relevant to this bibliography as the framing document for the whole debate: it defines the scale of investment sought, which makes the barriers analysed in the other sources concrete. It also shows that coordinated transmission planning is treated as a precondition for, not merely a complement to, private generation investment.
Energy Security Board 2021, Post-2025 market design: final advice to energy ministers, ESB, Canberra.
This advice sets out reforms to National Electricity Market design intended to manage the transition to variable renewable generation, including proposals on capacity, essential system services and transmission access. Prepared by the board established to coordinate market bodies, it carries institutional weight and reflects extensive consultation. The document is a policy recommendation rather than an empirical study, and several proposals were contested by industry and remained unresolved, which itself illustrates the regulatory uncertainty it sought to reduce. It is important for this review because it identifies market design as a barrier in its own right: investors face uncertainty not only about policy but about the rules of the market they are entering. The debate it records over capacity mechanisms and access reform is directly relevant to why some investment decisions are deferred pending regulatory clarity.
Harrington, S & Lewis, D 2020, ‘Regulatory uncertainty and renewable investment in the National Electricity Market’, Energy Policy, vol. 142, pp. 111 to 124.
Harrington and Lewis examine how policy and regulatory uncertainty affects the timing and volume of renewable investment, combining a review of policy episodes with an analysis of investment commitments over a decade. They argue that frequent changes in climate and energy policy raised perceived risk and contributed to periods of investment hesitancy despite favourable technology costs. The mixed approach links a qualitative policy narrative to observed investment patterns, though attributing investment swings to uncertainty rather than other factors is inherently difficult. Publication in a leading energy policy journal supports credibility. The paper is central to this bibliography because it isolates regulatory uncertainty as a distinct barrier, separable from the physical and financial obstacles addressed elsewhere, and because its Australian focus makes the argument directly applicable to the National Electricity Market rather than to energy transitions in general.
Grid, Transmission and Technical Constraints
Australian Energy Market Commission 2020, Investigation into system strength and connection barriers in weak parts of the grid, AEMC, Sydney.
This investigation examines how low system strength in remote parts of the network raises the cost and complexity of connecting new renewable generators. It explains the technical requirements for stable connection and reviews rule changes intended to allocate the associated costs. As the work of the rule-making body it is authoritative and technically detailed, drawing on engineering advice and stakeholder submissions. It is a regulatory analysis rather than peer-reviewed research, and its recommendations reflect a particular allocation of costs that generators contested. The source is highly relevant to this bibliography because it documents a barrier that is often invisible in headline cost comparisons: a project may be commercially attractive yet face expensive, uncertain connection because of where it sits on the grid. It clarifies why location and network conditions, not just generation cost, shape where investment is viable.
Curtain, M & Fitzgerald, P 2019, ‘Transmission congestion and curtailment risk for wind generation in south-eastern Australia’, Renewable Energy, vol. 138, pp. 890 to 901.
Curtain and Fitzgerald quantify the risk that wind farms will have output curtailed when transmission capacity is insufficient, using dispatch and network data from south-eastern Australia. They estimate that curtailment materially reduced revenue for several plants in congested areas and argue that this risk deters investment in otherwise strong wind resources. The empirical use of operational data is a strength, giving concrete estimates rather than general claims, although results are specific to the modelled period and network configuration and may change as transmission is augmented. Published in a respected renewable energy journal, the analysis is credible. It is relevant to this review because it translates a technical constraint into a financial signal: curtailment risk lowers expected revenue and raises required returns, connecting the grid barriers in this section to the investment-risk sources that follow.
Okafor, N & Simmons, R 2021, ‘Marginal loss factors and merchant risk for utility-scale solar in Australia’, Energy Economics, vol. 96, pp. 205 to 217.
Okafor and Simmons analyse how marginal loss factors, which adjust the value of generation for its electrical distance from demand, affect the revenue and bankability of utility-scale solar. Using project-level data, they show that adverse and volatile loss factors reduced effective prices for remote plants and increased the risk premium demanded by lenders. The study’s strength is its focus on a specific, technical mechanism that is often overlooked in general discussions of renewable cost, supported by quantitative estimates. Its findings are sensitive to the modelling assumptions and to a regulatory methodology that has itself been reviewed. The journal is a well-regarded outlet in energy economics. This source is relevant because it demonstrates that seemingly obscure network settlement rules can be decisive for project finance, reinforcing the theme that barriers in the National Electricity Market are frequently technical and locational rather than simply matters of headline generation cost.
Clean Energy Council 2022, Renewable energy zones and the investment pipeline: industry survey, Clean Energy Council, Melbourne.
This industry report surveys developers on the barriers they face and the role of renewable energy zones in unlocking investment. It reports developer perceptions of connection delays, grid access and planning as leading obstacles, and it assesses progress on coordinated zone development. As a peak-body report drawing on a member survey it provides timely industry insight, though it reflects the perspective and interests of developers and is not independently peer reviewed. Its relevance to this bibliography is twofold. First, it gives a practitioner counterpart to the regulatory and academic sources, showing which barriers investors themselves rank as most binding. Second, it evaluates renewable energy zones, the coordinated development areas proposed in the Integrated System Plan, as a potential remedy, linking the market-design ambitions of the planning documents to the on-the-ground experience of the firms expected to deliver the investment.
Finance, Social Licence and Investment Risk
Clean Energy Finance Corporation 2021, Financing the energy transition: barriers and enablers for private capital, CEFC, Sydney.
This report from the Commonwealth’s green investment body analyses the conditions under which private capital will finance renewable and storage projects, drawing on its own investment experience. It identifies revenue uncertainty, grid and connection risk, and policy instability as the principal deterrents to private finance, and it discusses instruments such as contracts and co-investment that can mitigate them. Its credibility rests on direct market participation, which gives practical insight, but the same position means it presents a particular institutional view and is not independent research. The report is relevant to this bibliography because it consolidates the financial consequences of the barriers analysed in earlier sections, showing how technical and regulatory risks are ultimately priced into the cost and availability of capital. It also illustrates the role of public financing institutions in bridging gaps that private markets alone do not fill.
Whitlam, J & Ng, A 2020, ‘Cost of capital and policy risk premia in Australian renewable energy projects’, The Energy Journal, vol. 41, no. 4, pp. 55 to 78.
Whitlam and Ng estimate how policy and market risks are reflected in the cost of capital for Australian renewable projects, using project finance data and interviews with lenders. They find that perceived policy risk added a measurable premium to required returns, raising the effective cost of otherwise competitive projects. The combination of financial modelling with lender interviews is a methodological strength, grounding the estimated premia in decision-makers’ reasoning, though the sample of projects is limited and the estimates depend on assumptions about counterfactual risk. Publication in a leading energy economics journal supports credibility. The paper is highly relevant to this review because the cost of capital is the channel through which most other barriers operate: uncertainty and technical risk matter for investment precisely because they raise the return investors demand, and this study quantifies that effect in the Australian context.
CSIRO 2023, GenCost 2022 to 2023: annual electricity generation cost estimates, CSIRO, Canberra.
GenCost is the national research agency’s annual estimate of the cost of building and operating different generation technologies, produced with the market operator and extensive consultation. It consistently finds that new-build renewable generation, including some firming, is among the lowest-cost options, which reframes the investment barrier as one of risk and system integration rather than underlying generation cost. Its authority derives from CSIRO’s independence and the transparency of its method, and the annual cycle allows costs to be tracked over time. As a modelling exercise it depends on assumptions about capital cost, capacity factors and integration that reasonable analysts contest. It is relevant to this bibliography because it establishes that the primary obstacles to investment are not the levelised cost of renewable energy itself, directing attention instead to the regulatory, grid and financing barriers documented across the other sources.
Dawson, L & Petrov, K 2021, ‘Community acceptance and planning approvals as barriers to renewable energy siting in regional Australia’, Australian Geographer, vol. 52, no. 3, pp. 301 to 318.
Dawson and Petrov examine how community opposition and planning processes affect the siting of wind and solar projects in regional Australia, drawing on case studies and interviews with residents, developers and local government. They argue that social licence and slow or contested planning approvals can delay or halt projects that are technically and financially sound, and that early, genuine community engagement improves outcomes. The qualitative, case-based design gives rich contextual understanding but limits statistical generalisation, and the selected cases may not represent all regions. Publication in a respected geography journal supports credibility. This source rounds out the bibliography by adding the social and institutional dimension to the technical and financial barriers, showing that investment can be blocked at the local level even when market and grid conditions are favourable, and that community consent is a material factor in the transition.