Should Australia follow Argentina and introduce a National Regime for Distributed Generation?

Share on twitter
Share on linkedin
Share on facebook

One year ago, I arrived in Buenos Aires for the first time. Heading to a salsa club in the fashionable Palermo Soho district, my partner and I discovered that not only the club, but the entire city block, was pitch black. Chatting with fellow salseros in the dark we were informed that, yes, this kind of power outage was normal and no, power would not be restored any time soon.

Power outages both planned and unplanned are not uncommon in Buenos Aires. In February of this year, a power outage on one of the hottest days of the year left around 370,000 people in the city without power. Of course, unplanned outages and load shedding happen in Australia too. As in Argentina, the catalyst for outages tends to be heat wave events where residential consumption soars.

In today’s article, I look at how Argentina’s new distributed generation regime (the Regime) is intended to strengthen reliability and security in the grid and how this compares with the Australian policy settings for distributed (or ‘embedded’ generation).

Distributed Generation

Photo by Sasha • Stories on Unsplash

By Dr Drew Donnelly, Regulatory Specialist, Compliance Quarter

1. The Similarities in the Argentine and Australian Energy Landscapes 

There are some instructive similarities between Argentina and Australia when it comes to energy:

• Abundant natural gas resources, with a significant quantity being exported;
• Enormous renewable energy potential (solar for Australia and Northern Argentina, wind for the vast Patagonia region);
• A federal system of government with substantial devolution of energy policy to regional jurisdictions (states and territories in Australia, provinces and the capital in Argentina);
• Strong population growth and ‘clumping’ in certain areas as opposed to even distribution (focused on the south-eastern seaboard in Australia, and on the banks of the River Plate in Argentina);
• Extreme temperature variation across seasons, including heat waves in summer.

As mentioned earlier, the last similarity is the catalyst for power outages in both countries. However, the underlying cause of outages in both countries are distinct. In Argentina, the outages are caused by heavily degraded network infrastructure, including low-voltage wiring and transformers. The network infrastructure fails when consumption is high. By contrast, in Australia, a key contributor to outages has been the proliferation of non-dispatchable renewables such as wind and solar and a technical limit on importing dispatchable generation from adjacent states via interconnectors.

Like Australia, Argentina struggles with the same question that guided the Finkel Review; how does any nation in the 21st century balance a secure and reliable energy system with one that is affordable and meets emissions targets? The Australian Commonwealth Government’s response is the National Energy Guarantee (the NEG) with its ‘reliability’ and ‘emissions’ obligations. However other important initiatives that are part of the Government’s response are distributed/embedded generation and demand response initiatives. Distributed generation is electricity generation by many separate electricity users at their point of consumption (such as through rooftop solar photovoltaic (PV) or an in-house diesel generator).

2. The Argentine Response: Distributed Generation

Argentina has not developed a market-based response (such as the NEG) to the ‘Finkel question’. With respect to reducing emissions, the Federal Government has set a renewable energy target of 20 per cent renewables by 2025, which is supported by ‘RenovAr’, a series of public bidding rounds for renewable investment with long-term Power Purchase Agreements (PPA). Through this, the Argentine Government expects US $15 billion of renewable investment.

What about dealing with power outages? The Australian example has shown that, unless other measures are taken, investment in renewables can be negatively correlated with system security and reliability. As a part-solution, as well as an attempt to increase renewable generation, in November last year, the National Congress passed a law titled the Promotion Regime for Distributed Generation of Renewable Energy Integrated in the Public Electricity Grid (the Regime). This is designed to increase the use of solar PV in dwellings and hence reduce the load drawn from the grid during extreme weather events.

The key elements of the Regime include:

• a procedure that the customer, the ‘user-generator’, must follow with the distributor for authorisation to connect to the grid;
• obligations on the user-generator and the distributor to sign a distributed generation agreement;
• a billing framework to compensate the user-generator for the value of their energy ‘injected’ into the grid through a ‘net metering’ mechanism;
• a prohibition on distributors charging access fees or any other kind of tax associated with the installation of distributed generation systems;
• a fund for distributed generation, which will be used for grants, loans and other incentives in order to support take-up by customers;
• a framework for tax incentives and other support (such as preferential financing) for the manufacture of equipment that promotes the distributed generation of renewable energy; and,
• an obligation to incorporate distributed generation systems in national public buildings.

Regulations setting out the operational details of the Regime are under development and should be released shortly.

3. Differences between the Argentine and Australian approach to Distributed Generation

We discussed some core elements of the Australian approach to distributed or ‘embedded’ generation at What are the key differences between the Regime and the Australian approach?

• It is a federal approach, standardising the rules for distributed generation across the country. While some rules for connecting embedded generation are contained in the National Electricity Rules in Australia (and therefore apply across the National Electricity Market (NEM) jurisdiction), many matters including funding, pricing and licensing requirements differ significantly by state/territory;
• The Regime prohibits connection charging by the distributor. This is permitted in Australia. This could further incentivise distributed generation in Argentina. On the other hand, this will be facilitated by Government subsidies to distributors, the details of which are not yet available. If the subsidies are not sufficient then distributors will inevitably cut costs somewhere (such as cutting investment in new network infrastructure);
• The Regime legislates nationally for distributed generation to be settled by net-metering. That is, the customer’s electricity consumption bill will be discounted by the amount produced and fed into the grid. While Australian jurisdictions have moved to a net (rather than ‘gross’) metering regime in recent years, some argue that this disincentivises solar investment. In particular, this may be an insufficient financial benefit to encourage battery storage of solar. In Australia, at least the tariff structure can be varied by states and territories depending on their success.

On the one hand, a nationally uniform approach to distributed generation, such as Argentina’s, may be beneficial in publicising, simplifying and clarifying for everyone the rules for distributed generation and solar PV. The Australian approach with considerable differences in rules between states and distribution network areas can be confusing and result in some states/territories (with the more supportive distributive generation arrangements) carrying a disproportionate burden. On the other hand, whether or not distributive generation will be successful in reducing the burden on network infrastructure ultimately depends on the economics of that investment. Currently, the prohibitive cost of solar PV equipment in Argentina, and lack of clarity around subsidies means that a substantially increased uptake in distributed generation is some way off.

[1] See

[2] It is usually claimed that this network under-investment is a result of utility price freezes by successive Governments meaning that distributors have had insufficient funding to upgrade the network for population growth. For more, see

[3] See Independent Review into the Future Security of the National Electricity Market – Final Report (the ‘Finkel’ Review), p36-40.

[4] For more information, see

[5] To learn about demand response, see

[6] For more information see

[7] See

[8] See

[9] As a result of high import duties, and lack of local manufacturing, it is estimated it would take 12-13 years for a customer to recover their solar PV investment. See

More to explorer

notes on board

How to Manage Multiple Compliance Deadlines: A Case Study

Compliance managers in the energy sector are constantly juggling a large work load with competing deadlines. Managing time effectively is a core skill for compliance managers. In this article, we will present a hypothetical case study of a compliance manager in an energy retailer who has to juggle multiple compliance tasks and deadlines, and how they can use some strategies and tools to manage their workload and prioritise effectively. We will also share some insights and tips from Compliance Quarter,

laptop on table top

How to Avoid Compliance Risks by Effective Communication: A Case Study

Compliance managers in the energy sector face many challenges in ensuring that their businesses comply with the regulatory framework. One of the most common and frustrating situations is when their advice is ignored or overridden by senior management or other stakeholders, exposing the business to potential compliance risks and penalties. In this article, we will present a hypothetical case study of a compliance manager in an energy retailer who faced this scenario and how it affected the business outcomes. We

Contemporary design of multifamily living houses. Modern luxury apartments buildings.

Modernising Electricity Regulation: The AES Framework and Embedded Networks in Western Australia

Background The existing licensing framework overseeing the sale and supply of electricity in Western Australia (WA) has struggled to adapt to the rapid expansion of emerging and atypical electricity business models in recent years. To address this, in 2019, the then Minister for Energy commissioned Energy Policy WA to assess the regulatory framework in Western Australia. In 2020, Energy Policy WA initiated consultations on a proposed regulatory framework for various categories of ‘alternative electricity services’ called the Alternative Electricity Services

Leave a Reply

Your email address will not be published. Required fields are marked *