Tag: national electricity market

Confident with no confidence – QLD style CID

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Asking a cursory ‘Trust you are having a good and Happy Easter up in Queensland’. The reply was a shocker: “We are stuffed, I suppose the next thing we will get is a letter in the mail, stating we have to walk off our property so they can push every thing over for Ergon and the mines – Love Sharron”.  What was referred to is an alleged flawed process for the duplication of the 63 klm long 110kV power line from Warwick to Stanthorpe in Queensland, and the mounting speculation a public announcement has been held back from that process.

Ergon Energy is sponsoring the Community Infrastructure Designation (CID) process, under the Section 200 of the Sustainable Planning Act 2009 (SPA). The SPA details the process required for CID, providing an emphasis on ensuring that adequate environmental assessment and public consultation occurs prior to Queensland Government approval.

But it is suspected Ergon Energy has not been fully consultative with landowners and the community on the proposed corridor and cracks are appearing in the approval tactics under the Queensland Government’s CID process. According to the ‘grape vine’ what is held back is announcing mining is coming to Warwick, which is backing off Cherribar Resort owned by Chinese investors (a Resort set up to supply 400 homes for dignified living of people of Chinese origin), and the facilities includes the operating of their own airstrip. The timeframe is said to be in about 18 months, and soon after Cecil Plains coal seam gas and open cut mining has started.

CO2Land org then felt compelled to research this story further and then noted the Southern Free Times has been running stories on the progress of the proposal by Ergon Energy to build an additional power line to supply the Stanthorpe area. A quick check indicated this means 3 supply lines to cater for the area. (Stanthorpe – translated as old English meaning ‘tin town’ – is a town situated in south east Queensland, Australia. The town lies on the New England Highway near the New South Wales border 223 km from Brisbane via Warwick, 56 km north of Tenterfield and 811 m above sea level. The area surrounding the town is known as the Granite Belt. At the 2011 census, Stanthorpe had a population of 5,385.)

According to the local government council, the population of the Southern Downs Region has increased over the past 5 years at an annual average rate of 1.4%.  They say this rate is above the national average for inland regions not affected by the current resources boom. They also say the population increase has been brought about partly by the “tree change” phenomenon, and partly by the affordability of high quality housing – currently averaging 40% less than Brisbane prices. That said it would be hard for Ergon Energy to argue population growth numbers justifying such a large expenditure on an underutilized power line – at a community expense, certainly not justified for at least another 10 years without a resources boom planned!

However, the headline of Southern Free Times of 28 March 2013 read “Stanthorpe needs Power Reliability Says Springborg” – the opening paragraph included “The State Member said he remains confident in the decision making process of a Stanthorpe Power Line Community Reference Group, despite rifts in the group and a loss of community support”. Looking deeper into the story we find 6 of the 11 member CRG have resigned!    This sounds a bit odd – the State Member (also the Qld Gov Minister of Health) ‘remains confident’ and the CRG has no confidence in the CID process? So what is really going on here?

On reading the entire story it is noted a number of good points are raised in the Southern Free Times and the expected well scripted responses come from Ergon Energy.  But what was not covered were some big burning matters such as: Fair compensation for the loss of use or abandoning the use of your homes and property to make way for a duplication of the 110kV power line (it seem Qld in cutting the red tape for approvals also avoids the option of owners selling land affected at market price, or even accept a fair rent for the use of the land). Next, the line will be redundant unless significant growth for the need for power increases above the expected planned growth scenario. This is something the regulators must test for who benefits and whether the abandoning of the need in the lifetime of the line will result in undue costs to the community. Especially if the ‘grape vine’ is correct as to the actual need for such a large duplication.

The big issue in all this is not even remotely covered. That is the case for smearing the costs with the community when it may be a benefit for say a new mine or foreign investment interests, and that user might pull out of the area before the economic life of the line is reached.  We can think of numerous examples where this happens and one ripper is Cobar in NSW – the lines were put in and the mine shut down leaving the community to pay the costs. Costs that we now know could be avoided.

What evidence is there that financial and lifestyle costs could be avoided? The answer is actually in the responses from Ergon Energy to the Southern Free Times. A absolute major give away and indicator of the real agenda  – Ergon did not say that all alternatives had been evaluated, they said proposals to met expected demand for alternatives had not been included in time. They also said two lines currently serve the area including an 110kV and a 33kV line. They argued the 33kV line can only supply half of the current peak load. Extrapolate that to peak loads and the capacity of the current 110kv line is fine and allows for load growth of the predicted 18% over the next ten years. It also means demand response measures, if taken, will cater for peak load without new infrastructure. It also means a duplicate 110kV power line will at best be utilized 5% of the time – if you research the Power of Choice submissions with AEMO you will find similar analysis.

Also noted in Springborg’s response is he said new infrastructure was required and without detail other than a general statement the community is entitled to reliable power. Maybe the CRG should ask a few more questions, like:

  1. Why do you need more than what is stated as the need in growth scenarios (reference to published planning and forecasts from other than Ergon)?
  2. Why do you think technology will not provide solutions at a least cost other than conventional distribution of power? and,
  3. If a new industry development other than what is required by a community in growth were introduced would that industry pay a fair and reasonable rent for the infrastructure?
  4. Would a fair and reasonable rent be returned to the community?

Of course these questions are very likely to elicit more the well scripted replies to the questions, but then you could just ask them again only at a different level. For instance, if the state said the means is more important than the ends, it should be tested thoroughly.

Co2Land org now asks: If we consider the four primary schools of thought in general jurisprudence :

  •   Natural law is the idea that there are rational objective limits to the power of legislative rulers.
  •  Legal positivism, by contrast to natural law, holds that there is no necessary connection between law and morality and that the force of law comes from some basic social facts although positivists differ on what those facts are.
  •  Legal realism is a third theory of jurisprudence which argues that the real world practice of law is what determines what law is; the law has the force that it does because of what legislators, judges, and executives do with it. Similar approaches have been developed in many different ways in sociology of law.
  • Critical legal studies is a younger theory of jurisprudence that has developed since the 1970s which is primarily a negative thesis that the law is largely contradictory and can be best analyzed as an expression of the policy goals of the dominant social group.

Has the Queensland Government and Ergon (a government entity) set the theme of better practice or has the quest for the means of the market overtaken good policy for the ends to look after the community?  If the means is more important can we say the community consultation businesses that influence, is only in the interest of making a market other than setting up community representative groups with limited knowledge of the true agenda? Therefore are these groups only to give comfort to the Minister of state that all is well on a certain issue?

COAG Powers – playing ball EPBC, Energy Market Reform

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A business’s focus should not just be on project management, which is a reactive stance, but ’project mastery’ – this includes not allowing stakeholders to tug it in a multitude of directions, making it impossible to set clear goals and deliver the goods on time – finding the balance between sticking to the original plan and remaining flexible – avoiding ‘score creep’ (where the scope of a project is not properly defined, documented, or controlled) – and keeping to the path. Says The Harvard Business Review as sent out by Caring for our Country’s Garry Reynolds.

Linking how this could affect the effectiveness of the intention of the Council of Australian Governments (COAG) intentions (Meeting – Communiqué Canberra, 7 December 2012) from its 34th meeting in Canberra [As a note COAG has for 20 years been meeting to discuss Business and politics]. You could wonder it COAG can deliver despite it continues to reiterate its commitment to focus its attention on policy reforms of national significance, and to keep its agenda as streamlined as possible.

If we focus on COAG Environment and Energy Reforms:

Posted on December 7, 2012 by co2land “EPBC Powers – COAG passing the ball?” where we raised an analogy over federalism and enterprise models and “If you translate that to Federal and State and Territory government workings, you might see the possibility of a run away train through select enterprise if the influence is replaced by vested interest other than the good of society, or our long term future”, and then recently COAG, on Environmental Regulation Reform, “re-affirmed its commitment to broad environmental regulation reform that enhances efficiency and increases certainty for business, while maintaining high environmental standards”. It follows that the Commonwealth will progress its legislative reforms in response to “the Hawke review of the Environment Protection and Biodiversity Conservation Act 1999 to further streamline and strengthen environmental regulation”.

As we previously said COAG wants to articulate ‘standards’ that the Commonwealth has proposed and that State and Territory processes would need to meet these standards as ‘accredited’ arrangements. COAG writes it “represent an important milestone in COAG’s reform agenda” and “Jurisdictions have made consistent efforts to improve regulatory arrangements, including increased use of strategic tools and commitment to early engagement with proponents.  COAG welcomed the release of the Commonwealth’s Statement of Environmental and Assurance Outcomes and draft Framework of Standards for Accreditation”.

The issue may be in the following: “As a further step to improving processes relating to environmental regulation, COAG agreed that all jurisdictions will direct their regulatory and referral agencies to eliminate duplication and to avoid sequential assessments and delayed approval processes and also to utilise common information requirements for both assessments and approvals”. The operative being co-operation and avoiding ‘score creep’ as states and territories are known to seek.

Energy Market Reform, in 1996 we saw the introduction of the National Energy Market (NEM) and its strong appeal was for urgent and concrete action to reduce the price of energy through ‘contestability’. In 2012, “ COAG noted the strong call by business for urgent and concrete action on energy market reform to help moderate the impact of high electricity prices on consumers and business, particularly the need for greater access to more flexible pricing”.   While the concepts differ in that contestability was the original answer to lower energy rices, in particular Electricity prices, what COAG has now endorsed is a more comprehensive package of energy market reforms for jurisdictions in the National Electricity Market than in 1996. In this instance ‘reliability standards’ are to be addressed additional to rules and price.

Set up for the job of the reforms are, “the Standing Council on Energy and Resources (SCER), with advice from the Business Advisory Forum (BAF) Taskforce.  In addition to agreeing to the recommendations from SCER and the BAF Taskforce, COAG agreed in principle to adopt the new best-practice framework for reliability standards (to be developed by the Australian Energy Market Commission and which give primacy to affordability for consumers at agreed levels of reliability and take account of regional considerations) and to transfer responsibility for applying the framework to the Australian Energy Regulator (AER), with a final decision by the end of 2013”.

It is additional funding from the Commonwealth that is being made available to enable the AER to review “its resources, independence and operational arrangements”.

COAG secretariat acknowledges the full implementation of the reform agenda (to be taken forward by Energy Ministers), “will take sustained commitment over time”, and the oversighting progress needs to be vigilant.  Further details on the reform package are available at www.coag.gov.au.

It should also be noted the domestic gas market is not forgotten and “COAG requested SCER to provide advice to its next meeting on challenges facing domestic gas markets”.

A bit more from Caring for Our Country co-ordinator, Garry Reynolds:

The International Energy Agency is projecting a glut of energy as the US becomes the largest producer of oil and an exporter of gas – CO2 emissions will continue to grow, but energy efficiency could help buy us time in addressing climate change and save money. Source: Climate Spectator 13 Nov 12.

Global demand for fossil fuels, especially coal, is forecast to grow strongly – yet carbon emissions will have to peak soon if the worst of climate change is to be avoided – coal met 45% of the growth in global energy demand between 2001-11 – roughly triple the contribution from renewable energy sources such as solar and wind. Source SMH 17 Nov 12.

Australia is betting big on the expansion of coal as the world’s 4th largest producer (6% of the world’s coal production) – committed projects to expand coal capacity total $9.8 billion for ports and $16.7 billion for mines – the Government is hoping that the long term development of carbon capture and storage will mitigate the greenhouse effects of the expansion.  Source SMH 17 Nov 12.

Because of the variability of wind and solar power, every 1,000 megawatts of renewable energy production capacity needs 600 megawatts of coal or gas power as a backup. Source SMH 17 Nov 12.

The US glut of cheap natural gas is leading major coalminers to look to the construction of new ports on the US West Coast to massively increase exports to Asia. Source New Scientist 13 Oct 12.

Hydro Tasmania is the largest generator of clean energy in Australia. Source Planet Ark 24 Oct 12.

Australia’s 20 per cent Renewable Energy Target has delivered $18.5 billion in investment, with the potential for $18.7 billion more if the policy is retained in its current form according to the Clean Energy Council – it is cutting emissions and paying for itself. Source  REneweconomy 25Oct 12.

And, the best for last : ‘Innovation is obvious in hindsight and radical in foresight’ Hargraves Institute 23 Oct 12.

Co/trigeneration sequel – Balancing Energy in your Business

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In its draft report on Electricity Networks and the Regulatory Frameworks the Productivity Commission encourages a standard approach to Embedded generation (12.2) and puts a focus on minor distributed generation such as PVs, VAWTs etc (13), and the disparities in tariffs. The general theme is to push toward time based pricing to assist technologies where it can be incorporated within a strategy of load lopping.

On 4 November CO2Land (www.co2land.org) posted “Balancing Energy in Your Business” and a quote from the story said “It might be time, if you have not already, consider curtailment opportunities, renewable generation, cogeneration or trigeneration (albeit some high profile projects may well prove to be an embarrassment for overblown claims), or combinations of technologies with emphasis on energy savings.” This sequel further explains the pros and cons of cogeneration and trigeneration. The message is fully understand it first!

Increasingly common, where gas connections are possible, is the embedding of co-generation and there is an increase trigeneration. A little 101 here:

  • Cogeneration: Also known as combined heat and power, cogeneration uses wasted heat from gas-fired engines to project into other processes such as generating more electricity or producing heating.
  • Trigeneration: Combined cooling, heat and power – goes a step further, simultaneously producing power, thermal energy and cooling. The cooling can be used for production processes or climate control.

Gas Today (www.gastoday.com.au/news/benefits_of_cogeneration_and_trigeneration/078333 ) ran a story on Benefits of cogeneration and trigeneration where the authors said: “Cogeneration and trigeneration are already well established in Australia, with a growing clientele of property owners and developers incorporating them into their new or existing buildings or plants. Flexibility in design makes these applications easy to adapt to different customer demands, and thus cogeneration and trigeneration plants can be found in various different locations, including:

  • Urban areas with office buildings or retail complexes;
  • Residential areas;
  • Industrial or manufacturing facilities, such as breweries, abattoirs and dairies;
  • Hospitals;
  • Education facilities including universities and schools;
  • Airports;
  • Government sites such as state and federal agencies; and
  • Data centres.”

However, with all good marketing efforts should come the balancing with ‘real’ stories. After reading a post of Dru Spork (Manager at Grocon in Sydney), he made the comment  “those with experience should be able to chuckle along with this”, and what did he mean? Pitfalls we suspect and what to avoid when sizing. Some common mistakes and problems are:

  1. Design size for load lopping rather than operation. This can mean the unit is insufficient to handle the building load if isolated from grid connection.
  2. Total reliance on standards measures (AS3000) design ratings and not correctly sizing to match operation. That is not measuring correctly the actual equipment selections coupled with absorbed power/run power modelling.
  3. Not considering the ‘what if’ on the power requirements when other energy efficiency initiatives or technologies are introduced. Will there be a need to run the generator?
    The economics are very important for the business case and overblown estimates could mean a stranded asset. Consider:
  • The Capex investment for different load operations.
  • Modelling the generator operation modeled at say 100%, 75% and 50% load (to predict available electrical load) and match this to absorber performance at 100%, 75% and 50% – rather than checking the quality of the heat output and how this works with the absorbers.
  • Determine building heat load in the operational model.
  • Be prepared for battles with the electrical authorities over fault levels and approval procedures (project approvals can take around 18 months).
  • Empty buildings do not need power. The operations modelling of the generators assume occupation and operations of the building.

CO2Land org considers it is not uncommon that such projects fail and it tend to be because the introduction was not planned as well as it should have been. When talking to Ahmed Abdoh, he said “that is why we in Carbon Training International offer the only nationally recognised course in Cogeneration and Trigeneration that can help how to take the right decision on size and type. check out our course on www.co2ti.com . The primary material of the Course is the work of Winton Evers (Ecoprofit Management) and Ahmed Abdoh (CO2Planet) moderated by Bill McGhie (CO2Ti).

We also ask you to consider, you will get noise complaints from the adjacent buildings when operating, you will not get $120 per KWH value every day for generating, for these projects a ‘too analytical’ engineering report is a good report!

Balancing energy in your business

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In previous arguments the Zero Waste community has been either instructed or advised that revenues from electricity generation using waste materials have no economic benefit, or are too little in the amount of return to be feasible. Other reported arguments are that the material products from the waste stream process have a significantly higher value than generation revenue. Those assumptions can be assumed to be no longer relevant if we approach the problems in a different light. Nor should we discount that technology will advance many techniques and the risk of each decision should be taken on a case by case and/or site by site basis.

If you consider the traditional energy procurement approach: You enter into a standard contract agreement, you concede the terms of your connection conditions and may actually be penalized if you fail to take the load assignment. The problem from this perspective is the supply side is assumed the only legitimate interest in providing energy security. The concept of energy is more legitimate if you refer to the supply and demand balance.

All community is affected by the rising cost of energy, and a number of specialist companies are offering products that approach the three essential considerations in the cost of energy: The energy price, the delivery cost and the carbon price. Something is being done and the “Power of Choice” is doing what it can to address the issues.

The reasons to accept that change is possible is the AEMC and the Senate are the essential bodies that will influence and inform how the implementation of an effective balancing of the National Electricity Market (NEM) and that Demand Participation is the result that is saving $billions for the community, and continuous saving thereafter. If you think this is a relatively new idea, the reality is under the term Demand Response (DR): Alan Fels, Chair of ACCC, on 19 November 2001 made a considerable issue the balancing equation; The Parer Review 2002 presented “Towards A Truly National And Efficient Energy Market”; The EUAA April 2004 presented “Trial of a Demand Side Response Facility for the National Electricity Market”; The ERIG Review November 2006 advocated “Review of Energy Related Financial Markets”; AEMC (formerly by NEMCO) carried Stages 1 & 2 of the Demand Side Participation Review and Stage 3 is in progress.

What does this means if you want to design or reengineer your process products under carbon constraints? On the 1st July 2012 some 250 Australian businesses became lawfully liable to pay $23 for every tonne of CO2e emitted from ‘operational controlled’ facilities emitting 25,000 tonnes or more of scope 1 Greenhouse Gas emissions. A recent survey by the Australian Institute of Management (AIM) revealed that only one third of the organisations surveyed agreed or strongly agreed with the question “My organisation is prepared for the implications of the carbon tax”. It follows that an organisations’ total carbon capabilities are critical to creating the transformational business response necessary to not only remain competitive in the short term, but to prosper in the long term. The process for creating this outcome is heavily dependent on having essential carbon management knowledge and skills in place, and an awareness of the commercial & competitive impacts under the carbon pricing mechanism. Small to medium enterprise (SME) are not a liable entity, at the time of writing and where you may not have as yet assessed the impact of the carbon price, you should be aware the large liable businesses pass the cost down through the supply chain.
The supply chain and operating costs will be having an impact on all consumers and suppliers. We know government assistance programs are available to help mitigate the cost pressures & fund critical investment in areas such as energy efficiency. What we do additionally can be our benefit in reducing all manner of waste including energy and energy products.

On 17 October 2012 the Clean Energy Regulator issued a report, and as a selective reference, said that the year ahead is focused on amongst other things ecological sustainable development and that will favour the innovators prepared to rethink business as usual. The Australian Tax Office (ATO) also provides R&D incentives offsets for those groups, and the Productivity Commission encourages rethinking.

It might be time, if you have not already, consider curtailment opportunities, renewable generation, cogeneration or trigeneration (albeit some high profile projects may well prove to be an embarrassment for overblown claims), or combinations of technologies with emphasis on energy savings.

CO2Land org is aware of licensed energy retailers that are operating where you will be rewarded for sharing risk in the energy price, similar companies also can offer demand incentives that you might also have though less than likely. In this scenario at least one retailer will individually profile the site and make an offer for the output or develop a hybrid contract to suit.

Some of the products developed or can be adaptive to your needs to be developed is:

  1. For generators:

Short term grid balancing, renewable and base load, hedging strategies, Greenpower.

  1. Auto load management with shed load or transfer to generator capability
  2. Price substitution, Load shed offers.
  3. Structured options according to risk tolerance and managed adjustments.

The message is you are no longer obliged with the status quo as a price taker, and you can start the discussion and work for what works for you.

If you are confused with the terminology, hopefully the following will help you better understand: The energy market has three components that affect the price we pay: Price response (PR), Demand Response (DR) and the Emergency response (ER).  Electricity price is proven to be largely inelastic, and as we are more reliant on alternative energy sources we notice the costs tend to be absorbed. Therefore our only real option to mitigate the price is a Demand Response (DR). DR is proving its ability to offset the most volatile price driver in the market. For the supply side the capex and opex growth on the distributed network is a large cost driver, generation is the marginal cost of capital to develop the projects. Demand Participation (DP) can help slow down the cost drivers and the supply side will welcome the cost reductions or the ability to reduce accelerated infrastructure build times. In this instance think build and increase capital required for infrastructure projects (pole and wires builds and maintenance needs to cater for the demand growth). Emergency Response (ER) is an energy security problem and is reactionary to large events with little warning.

CO2Land org also notes success with DP and that DR has been implemented in a number of electricity markets. This includes DR for Reserve Capacity in Western Australia’s Wholesale Electricity Market (WEM) which works very well.  In New Zealand, with a focus on frequency control being particularly important.

In hindsight, the lack of an effective DR mechanism in the NEM has cost electricity users an estimated Present Value (PV) of $15.8 Billion[1] (this is in the order of a 9% impost on their annual electricity bills).  The power to change is with you.

Previously CO2Land org posted, 7 Sept 2012, The Power of Choice – review by AEMC of DR and to recap the “Power of Choice” Review is an unfinished work, and CO2Land org has experience in the material of Demand Response (DR). DR is most effective as a formal aggregation of small amounts of demand reduction from a larger electricity users who are contracted to reduce this pre-agreed amount of their demand at times when their are extreme wholesale prices, extreme peaks in demand or in emergencies.  It is much cheaper way to address these short term events than our current outdated approach of spending billions of dollars on more generators and networks which are only needed for a total of about 40 hours per year.

References to support this view are:

[1]

  • Alan Fels, Chair of ACCC, speaking at the Inaugural EUAA Conference on 19 November 2001
  • The Parer Review 2002 “Towards A Truly National And Efficient Energy Market”
  • The EUAA April 2004 “Trial of a Demand Side Response Facility for the National Electricity Market”
  • The ERIG Review November 2006 “Review of Energy Related Financial Markets”
  • Stages 1 & 2 of the Demand Side Participation Review (Stage 3 still in progress)

Power of Choice – review by AEMC of DR

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All community is affected by the rising cost of energy. Something can be done, and the “Power of Choice” review being run by the Australian Energy Market Commission (AEMC) and a Senate Select Committee on Electricity Prices Inquiry is underway. Both these essential bodies need to be influenced and informed about how essential the implementation of and effective Demand Response (DR) is in the National Electricity Market (NEM) in saving $billions, and continuous saving thereafter.

Over the last 11 years there have been a number of Reviews that have made clear recommendations[1] that Demand Response (DR) should be implemented in our electricity markets.  Unfortunately, all these recommendations for implementation of DR have been ignored, with the exception of DR for Reserve Capacity in Western Australia’s Wholesale Electricity Market (WEM) which works very well.  In hindsight, the lack of an effective DR mechanism in the NEM in particular has cost electricity users an estimated Present Value (PV) of $15.8 Billion[2] (this is in the order of a 9% impost on their annual electricity bills).  Worse still this loss to the community is continuing to grow.

The “Power of Choice” Review is an unfinished work, and CO2Land org has experience in the material of Demand Response (DR). DR is most effective as a formal aggregation of small amounts of demand reduction from a larger electricity users who are contracted to reduce this pre-agreed amount of their demand at times when their are extreme wholesale prices, extreme peaks in demand or in emergencies.  It is much cheaper way to address these short term events than our current outdated approach of spending billions of dollars on more generators and networks which are only needed for a total of about 40 hours per year.

In the push for acceptance of DR becoming a part of the National Electricity Market (NEM) an article was written in the Daily Telegraph, 5 Sept 2012,  (link: http://www.dailytelegraph.com.au/news/power-shift-to-cut-household-bills/story-e6freuy9-1226465075377) after it was relayed some of the source contributions were gleaned from an EnerNOC sponsored report recently completed by CME.

CO2Land org and those mentioned in this post accept we look forward and hope the AEMC is now convinced that DR is essential to minimize further price rises.

If you are confused with the terminology, hopefully the following will help you better understand: The energy market has three components that affect the price we pay: Price response (PR), Demand Response (DR) and the Emergency response (ER).  Price is largely inelastic, and as we are experiencing alternative energy sources we notice the costs have similar or more Price effects to introduce them. Demand Response (DR) is the most volatile price driver in the market where smaller splices of time require a greater build and increase capital required for infrastructure projects (pole and wires builds and maintenance needs to cater for the demand growth). Emergency Response (ER) is an energy security problem and is reactionary to large events with little warning.

References to support this view are:

[1]

  • Alan Fels, Chair of ACCC, speaking at the Inaugural EUAA Conference on 19 November 2001
  • The Parer Review 2002 “Towards A Truly National And Efficient Energy Market”
  • The EUAA April 2004 “Trial of a Demand Side Response Facility for the National Electricity Market”
  • The ERIG Review November 2006 “Review of Energy Related Financial Markets”
  • Stages 1 & 2 of the Demand Side Participation Review (Stage 3 still in progress)

[2]