Dinosaurs don’t dance, or why storage will not be the light at the end of the tunnel for networks

Last week I took part in an Oxford-style debate as part of the Australian Energy Storage conference, where myself and two industry colleagues argued that energy storage would NOT be the light at the end of the tunnel for electricity network operators.

This post is a summary of our arguments, which we presented with success to claim victory in the debate.

Sadly for electricity network operators, dinosaurs don't dance (Photo: https://www.flickr.com/photos/jasminel/8140833334/)

Sadly for electricity network operators, dinosaurs don’t dance (Photo: Uncommon Jasmine)

Our overarching argument was “DINOSAURS DON’T DANCE“, which we evidenced as follows:


  • FACT – network business model matured in the first half of the 20th century (= before TV)
  • PRECEDENT – telco, airline businesses are unrecognizable from before deregulation in the ‘70s
  • FACT – transfer of capital expenditure/benefits realisation to customer runs completely counter to network business model/culture
  • FACT – Australian governments currently own around 75% of electricity network assets in the NEM, and a greater share for Aust as a whole
  • FACT – in 2008/9, R&D undertaken by electricity networks across Aust was less than 1% of the value added, or about the same as the log sawmilling and timber dressing industry


  • FACT – networks are unable to capture all the benefits and are unable to collaborate
  • FACT – network incentives will have to go via the retailers, who own the customer relationship
  • FACT – continued shift to self-generation will most heavily impact networks
  • FACT – both the networks and the AER base their revenue-cap calculations on projections of future demand, which draw heavily on historical data at the expense of future technologies such as storage (which may reduce demand forecasts)
  • FACT – networks are incentivized to avoid risk and by extension new technology
  • FACT – RWE/Germany business model had to break before they adopted the “Future Utility” model, which is less profitable than the old model
  • QUOTE – “rate-of-return regulations … create incentives for inefficiency by encouraging cost padding”, Productivity Commission inquiry into Electricity Network Regulatory Frameworks, 2013
  • QUOTE – “If the regulator cannot obtain sufficiently reliable information on a business’s costs … it may be possible for the business to game the regulatory process by presenting information that leads to a high revenue allowance”, Productivity Commission inquiry into Electricity Network Regulatory Frameworks, 2013
  • QUOTE – “using past information to set future targets reduces the incentives of a firm to lower costs since it knows that it will decrease its revenue in the future”, Productivity Commission inquiry into Electricity Network Regulatory Frameworks, 2013
  • QUOTE – “Regulators do not have complete information about businesses’ actual costs, expenditures, demand and service quality, but they need to make judgments about what the ‘efficient’ cost might be and how long it should take a business to close any efficiency gap”, Productivity Commission inquiry into Electricity Network Regulatory Frameworks, 2013
  • QUOTE – “Regulators therefore face a trade-off in trying to create incentives for utilities to behave efficiently, while ensuring that customers share in benefits from efficiency gains”, Productivity Commission inquiry into Electricity Network Regulatory Frameworks, 2013
  • QUOTE – “if a network operates in a low risk way, and as a result, they can access lower cost financing, they can keep the difference between the actual WACC and the regulatory WACC”, Productivity Commission inquiry into Electricity Network Regulatory Frameworks, 2013
  • QUOTE – “When a business is faced with a choice between network investment and a DSP project and both have the same potential for earned returns, the business is likely to go with the “easier” network investment option”, AEMC Power of Choice, Dec 2014


  • FACT – benefits are fragmented across networks, retailers and customers
  • FACT – networks have no direct relationship with the customer (what about commercial/industrial?)
  • FACT – customers have a low level of awareness of their network operator (looking for the stat, but I heard it was less than 10%)
  • FACT – electricity providers are trusted by only 54% of households in Australia compared to the global average of 68% (CSIRO, July 2013)
  • FACT – financials for customer implementation will tip at the same time as for networks (particularly in the absence of FiTs/introd’n of connection fees)
  • FACT – Ergon Energy, one of the networks most affected by solar PV adoption, have submitted only two applications for exemption from ring-fencing against ownership of solar assets during the current 5 year regulatory period, and one of these was for their own offices
  • FACT – Vector experience proves that storage implement results in reduced revenue/kWh; Vector have yet to face up to any competition, and once this happens they’ll evolve into a completely different business from a network operator
  • QUOTE – “any individual business user has relatively little capacity to negotiate from a position of power with network businesses”, Productivity Commission inquiry into Electricity Network Regulatory Frameworks, 2013
  • FACT – the Distribution Annual Planning review process requires networks to have regard for Non-Network Alternatives, including those proposed by non-network providers
  • QUOTE – “Capital investment and technology is now flowing downstream into the customer installations”, Ian McLeod, CEO – Ergon Energy, Annual Report 2012-13


  • FACT – networks inability to force change in compensation for PV uptake will require them to downsize and become customer solution enablers
  • QUOTE – “When investors realize that a business model has been stung by systemic disruptive forces, they likely will retreat”, Edison Electric Institute, January 2013
  • FACT – from 2008 to 2013, the top 20 EU utilities lost half a trillion euros from their share value
  • QUOTE – “In their current state, utilities cannot finance Europe’s hoped-for clean-energy system”, The Economist, 12th October 2013
Your author accompanied by other members of the Aust Storage Conf 2014 debate (Photo: EcoGeneration)

Your author accompanied by other members of the Aust Storage Conf 2014 debate


How resilience is driving energy localisation

I’m presenting on this topic at the upcoming Clean Energy Week event in Sydney on 23 July 2014

Clean Energy Week speaker email footer

This article was originally published in Reneweconomy on 29 April 2014

How would you feel if you lost power for a week, even though your electricity provider knew this was likely to happen but did very little to avoid it?

For many in the U.S., this is exactly what happened in 2012.

In response, communities and businesses are pursuing local energy solutions.  Microgrids – one of the topics at next week’s Australian Energy Storage Conference – are being promoted by U.S. policymakers and adopted by end-users as a means of improving system resilience.

Although various definitions of microgrids exist, in simple terms they can be thought of as small-scale electricity networks that are independently capable and controllable from the surrounding grid.  While Australia has many examples of microgrids in isolated or island communities with power systems described as off-grid, standalone or remote, grid-connected applications are rare.

The increased focus on microgrids in the U.S. is being largely driven by efforts to harden the grid and reduce the impacts of events such as extreme weather.  By way of example, power outages caused by Superstorm Sandy in October 2012 cost an estimated $USD 14-26 billion and resulted in 50 deaths.  Microgrids can be used to strategically fortify critical infrastructure such as hospitals, police stations, public shelters and emergency response facilities with the ability to disconnect and connect from the main grid in times of widespread outages.

These investments to promote system resilience are aligning with other objectives to promote cleaner, smarter energy.  Project owners are incorporating increasingly larger amounts of renewable energy as a reflection of technology cost reductions and sustainability objectives.  These decisions reflect the ability to tailor microgrid design and operation to specific customer needs, in contrast to the ‘one-size fits all’ approach for regional-scale grids.

For corporates, resiliency translates as business continuity.  With the cost of unplanned outages necessitating uninterruptable and/or back-up power sources, the wider benefits and decreasing costs of microgrids are increasing their appeal.  The peak demand charges applicable to large electricity users provide an incentive for increasing levels of self-sufficiency, and are a direct input into the financial argument for commercial microgrids.  Data centres, which may access cost savings by switching to Direct Current (DC) power systems, have been identified as an early market application for microgrids.

So what of Australia?  Is our electricity system resilient?

The system vulnerabilities have already been exposed.  On 16 January 2007 around 690,000 Victorian electricity customers, including 70,000 businesses and public infrastructure services such as transport, telecommunications and healthcare, experienced electricity supply interruptions as an outcome from a fire in the northeast of the state in the vicinity of transmission lines.  Despite there being no direct loss of life and a mere 7 homes lost to the bushfires themselves, the total economic impact on the state was estimated at $500 million due to the supply interruptions alone.

The community ability to respond during the 2009 Black Saturday bushfires was severely hampered by the loss of power.  In Queensland around 200,000 people lost power after Cyclone Yasi in 2011, while some residents lost power for up to four weeks after Cyclone Larry in 2006.

Actions to address these vulnerabilities have been slow and largely superficial.  In 2010 the Australian Government released a national Critical Infrastructure Resilience Strategy that is based mainly on information sharing.

A request by Victorian distribution network operators to address climate risk in the period from 2011-15 by upgrading components of the network was declined by the Australian Energy Regulator, who were unpersuaded by the companies’ submission.

The long leadtimes of the electricity network price determination and infrastructure investment processes, combined with the steep learning curve for dealing with the ‘new normal’ of climate risk, suggests we are some way off from increased resilience being provided by the system operators.

Instead responsibility has been largely passed onto electricity users themselves.  In the wake of Cyclone Yasi, the Queensland Government published a guideline which recommended that “the relevant bodies undertake a review to identify the power supply security of critical infrastructure”.  As lead of the energy sector group for the Critical Infrastructure Resilience Strategy, the Australian Energy Market Operator advice on preparing for power interruptions is to create a business continuity plan and install back-up power supplies where appropriate.

And while network operators are currently ‘ring-fenced’ from providing services such as microgrids in a competitive market, the review of these guidelines has been deferred despite the Australian Energy Market Commission recommending they be reformed.

As per the U.S., the path forward seems therefore to be one of customer action.

Microgrids, which largely evolve incrementally from existing investments in distributed energy, represent the end-game in terms of going off-grid.  As technology cost reductions and network cost increases drive many towards this outcome, resilience simply strengthens the argument.

Microgrids for resilience: the U.S. experience... the infographic displayed at the Energy Networks 2014 conference in Melbourne

Microgrids for resilience: the U.S. experience… the infographic displayed at the Energy Networks 2014 conference in Melbourne


The emerging battle for the customer relationship

This post was originally published in the May 2014 edition of Utility magazine

As change gathers pace in the Australian electricity market, the entry of new players from telecommunications, entertainment and other service industries appears increasingly likely.  According to utilities and home service providers at February’s Smart Energy Summit in Austin, the key battleground will be for control of the customer relationship.

In its fifth outing, Parks Associates Smart Energy Summit: Engaging the Consumer examined the expanding market for energy solutions and home controls, along with their impact on utilities, service providers, retailers, manufacturers, and consumers.  Around 250 industry representatives gathered in the booming Texan capital to evaluate new partnerships, strategies for consumer engagement, and deployment plans for energy and management solutions in the Connected Home.

In an indication of the increasing importance of the topic, the event was around one third bigger than previous years.  Parks Associates’ breakdown of attendees highlighted the emerging competition from outside the sector, with an equal share of vendors, home service providers and utilities/energy providers.  My company Percepscion, a Melbourne-based home energy technology start-up, was invited to talk about our 2012 electric vehicle charging demand management project delivered with United Energy.

SES 2014 attendee breakdown

Attendee breakdown by industry at Parks Associates Smart Energy Summit in Austin, Texas, illustrating the cross-cutting appeal of the topic (Source: Parks Associates Research 2014).

Utility challenge from customer convergence

Presentations and discussions highlighted the convergence of energy and home service provider customer relationships.  Utilities, striving to adapt to more customer-centric business models, face a growing challenge from battle-hardened home service providers, who can leverage a broader and potentially more-compelling product portfolio beyond merely energy.

Utility heavyweights such as Duke Energy, Southern California Edison (SCE), San Diego Gas & Electric (SDG&E), Austin Energy, Reliant/NRG and TXU described their efforts to engage customers, who for the most part were described as apathetic.  Dennis Garman, Duke’s lead for Energy Management and Information, outlined their forthright efforts to engage customers through regular home energy reports.  In contrast Scott Burns, Reliant’s Director of Innovation, described their more passive approach of providing online tools for consumers who seek them out.

From the home services side, providers such as Lowe’s, Comcast and Alarm.com spoke of their success in engaging consumers with platform offerings that include energy management in the form of lighting and thermostat controls.  Tim Lott from Vivint described how his company has built out from home security services to now offer solar power system design, finance, installation and servicing.

Research presented by Parks Associates’ analysts helped explain the market development by pinpointing “lifestyle” as the most compelling aspect of the consumer value proposition.  Homeowners are seeking energy management solutions that provide greater convenience and improved amenity ahead of or along with cost savings.  In the context of the Connected Home, a typical quote that might sum up this sentiment may be, “My home makes my life easier and more comfortable, and even saves me money”.

Parks Associates research

Results from a survey of U.S. broadband-connected households, highlighting the overlap between energy and non-energy related products for the Connected Home (Source: Parks Associates Research 2014).


Future utility strategy – partner or compete?

The event underscored how the changing marketplace represents a tale of risk and opportunity for utilities.  Network services will continue to provide the business model foundation, on which utilities will then need to decide on their approach to the customer relationship.

The increased sophistication and growth in Demand Response program offerings from the utility industry was well represented at the event.  Austin Energy’s Debbie Kimberly described their connected thermostat journey, which is a key part of efforts to reduce peak load by over one third by 2020.  Anthony Hawkins, a group project manager for Landis+Gyr, reported on CPS Energy’s Virtual Power Plant initiative in nearby San Antonio which will support delivery of 50 MW or more of peak demand reduction into the ERCOT market in 2014.

Home service providers demonstrated their breadth and depth in terms of product offerings, national coverage and customer support.  Kevin Meagher from Lowe’s, a home products retailer with 15 million shoppers through their stores each week, described their approach to making homes safer, more efficient and easier to manage.  Joe Jankosky from Time Warner Cable, outlined the services delivered by their integrated home management platform including entertainment, home automation, health and wellness, energy management and home security, with car integration, garden and pet management, and presence applications in the pipeline.

Discussions arising from these presentations suggested that a potential path forwards may be utility-home service provider partnerships, where the distribution of responsibilities will reflect the natural alignment and strengths of each entity – home service providers will engage the consumer through brand recognition and compelling product offerings, while utilities will deliver Demand Response programs that leverage these products and enhance value to the consumer.

While this model had potential appeal to smaller utilities or those with a lack of brand recognition, the tensions arising around ownership of the customer relationship were felt to be a key obstacle, particularly for large vertically-integrated utilities.

CPS Energy Home Energy Manager app

CPS Energy’s Home Energy Manager app, the customer face of their Virtual Power Plants in San Antonio, Texas (source: CPS Energy).

Time Warner Cable IntelligentHome

Time Warner Cable’s IntelligentHome user interfaces, which include energy management functions such as heating/cooling and lighting controls (source: Time Warner Cable).

What does this mean for Australia?

Australia lags the U.S. on utility deployment of residential Demand Response and in the availability and adoption of Connected Home products and services.  However, with increased demand-side participation in the electricity market targeted by regulators and connectivity in the home growing daily, competitive pressures look set to increase.  As utilities ponder their transition to more customer-centric service provider models in response to increased solar uptake and affordable energy storage, the insights gained from the Smart Energy Summit may serve as a crystal ball into the future for Australian utilities.

When will electric vehicles provide grid storage?

This post was originally published in Reneweconomy on 28 March 2014

Close your eyes and picture yourself in a sleek new electric car – powered by clean electricity, emitting no pollution, silent and cheap to run.  Parked in your garage, it stores energy from your solar PV system to provide mobility and power your home.

But is it going to happen?… And if so, how and when?

The vision of parked vehicles being used for grid storage has captivated people since EVs began (re)emerging as a viable transport option – wind and solar variability could be solved through intelligent application of an underutilized asset!  Now with solar uptake booming in the U.S. and over 180,000 plug-in vehicles on the roads providing 4 GWh of potential storage capacity[1], the time has surely arrived to pull the pieces together?

The good news is that the technology is here or not far away.  Advanced vehicle/grid control systems can protect the battery and manage energy flows in line with network needs.  Interoperability across the various technology interfaces is advancing through the evolution and application of recognised standards.  These developments will provide enhanced visibility and control for network and vehicle operators, allowing them to cooperate easily, conveniently and for shared benefits.

The story from here will reflect the realities of car use, the insights from Big Data, and the power of visual association.

Experience has shown that vehicle owners are largely, but not entirely, predictable – most use their car during the day and charge overnight. While charging tends to happen when it is cheapest, drivers manage charging in line with the primary use of the vehicle as transport.  For energy service providers this translates to uncertainty – not a great foundation for business success.  When viewed alongside the relatively small storage capacity of individual vehicles relative to stationary batteries, the focus for the foreseeable future will be on the alternative.

The areas of opportunity are instead those with more certain benefits that outweigh the cost and effort involved in setting up the vehicle-to-grid system.

An obvious example lay in use of the cars for emergency back-up power, when access to electricity may be life-saving.  Equipment available now allows EVs to be used as a direct power supply independent from a hardwired electricity network.  Use of the vehicles as storage within independently capable and controllable microgrids has been identified as a means of providing increasingly valuable system resilience.

For non-emergency applications, the pathway will be through evolution of existing grid-connected installations – analogous to that unfolding for microgrids above.  Electric vehicles often operate out of locations that also feature distributed energy resources, such as solar PV.   This coincidence is intended, as the visual association of the two technologies provides significant “brand value” while in the early-market adoption phase.

Through analysis of the energy and vehicle activity data at these locations, much can be discerned about the opportunity for surplus energy to be directed to the cars when parked.  Individualized system design and control strategies can then be developed so as to deliver more certain benefits for only incremental investment.  These projects will serve as a stepping stone for the mainstream, commoditized solutions of the future, where cheap, clean and locally-produced energy is used for transport or stored in vehicles for later re-use.

Bringing these individual, site-based solutions together in the wider network context will unfold as local electricity market regulation allows and incentivizes it.  Regional operators may manage a number of distributed energy resources from across their network collectively as Virtual Power PlantsProjects of this type are already underway, endorsing the view of the future utility customer as a ‘prosumer’.  Through this model, a car may provide grid support from various locations within a network as it relocates over the course of a day – a scenario that represents the ultimate realization of the vehicle-to-grid concept.

For individuals who want to get the ball rolling, the first step would be to compare a record of vehicle movements with the generation profile of your home solar system.  Understanding the overlap will highlight the potential to generate your own transport energy.  Managing your EV charging to consume surplus energy generation may provide a financial benefit that would offset the absence of a feed-in tariff.

In the near-term the cost and effort involved will likely appeal only to the minority for whom the sometimes intangible benefits really matter.  These ‘early-adopters’, who will be strongly motivated by the visual synergy of co-located vehicle charging and solar generation, are a feature of any new technology adoption.

As the pathway seems clear and the technology is here, the future is now.

A co-located Electric Vehicle (EV) charging and solar generation facility at the CERES Environment Park in East Brunswick – an example project of the type that is a stepping-stone for EVs as grid storage (Source: CERES).

A co-located Electric Vehicle (EV) charging and solar generation facility at the CERES Environment Park in East Brunswick – an example project of the type that is a stepping-stone for EVs as grid storage (Source: CERES).

[1] Author’s calculation based on a breakdown of sales by vehicle type and battery storage capacity