By Michael Killeavy and Caroline Jageman
This article originally appeared on The Lawyer's Daily website published by LexisNexis Canada Inc. on November 11, 2019.
On Nov. 6, the Ontario minister of energy issued an order-in-council directing the Independent Electricity System Operation (IESO) to engage an independent third party to review existing generation and identify ways to lower electricity costs within such
The review is to focus specifically on larger gas, wind and solar projects
and portfolios of projects expiring over the next 10 years. The IESO is to
publish the third party’s report by Feb. 28, 2020. More worryingly, the
minister also expects that the IESO will identify additional opportunities to
lower system costs beyond the scope of the contract review.
While engaging a third party to find ways to reduce electricity costs may
seem commonplace enough, if implemented the way it has the potential
to be implemented, this direction could be the beginning of squeezing and
even terminating renewable energy and large gas projects in Ontario.
Over the last 15 years, the province through the IESO (and previously
through the Ontario Electricity Financial Corporation and the Ontario
Power Authority) has been entering into long-term contracts to purchase
electricity from renewable and large gas generators.
The reason Ontario uses long-term contracts stems from the failure of the
competitive electricity market launched by the Progressive Conservative
government in 2002. The competitive electricity market was transformed
into a hybrid market and the hybrid market did not generate the
necessary price signals to encourage new investment.
There was a severe supply crunch in 2003-2004 and consequently, the
province turned to long-term contracting to ensure resource adequacy.
Most of the contracts have terms of 20 years or more. A key reason for the lengthy terms is to allow project owners to obtain favourable, lower cost financing terms.
A long-term contract at a fixed price that is signed by a provincial corporation with the statutory right to draw on the electricity rate base is generally seen as less risky, and therefore requiring lower cost financing.
That was the state of energy policy until the spring of 2018, when a key election promise made by Premier Ford was to reduce electricity prices by 12 per cent. Despite this promise, electricity prices have been increasing. Similarly, in a consultation with industrial electricity consumers this spring, key feedback was that industrial electricity costs need to be lowered.
The above-noted direction may well be the first of a series of steps that the province is taking to reduce electricity costs. Based on this direction, the province will target large gas, wind and solar contracts to find savings. How the province extracts cost savings from these contracts will be key.
“Blend and extend” has long been rumoured as a possible means of reducing energy contract costs.
Blend and extend refers to reopening the energy contracts to renegotiate an extension of the contract term but at lower rates, and perhaps with other sweeteners thrown in. Project owners will enjoy a longer revenue stream if at somewhat lower payments. It can be a positive for project owners: after the point in time when the facility is fully paid for, the revenue becomes nearly all profit. Of course, project owners will need to make sure that the lower payment provides them with sufficient debt service coverage.
More drastically, the IESO may consider terminating these energy contracts. The IESO might offer to purchase out the term of the contract for a payment to be agreed between the parties. Alternatively, the IESO might terminate these contracts without a contractual termination right, in which case the counter-party would be entitled to damages. Theoretically, these termination costs would be added back to the rate-base, which would increase electricity prices.
Negotiations or legislation
If the IESO does proceed to blend and extend or terminate energy contracts, how the IESO implements these changes will be critical.
The IESO may entice project owners to come to the table with attractive buyout offers or a longer contract term. Potentially, the IESO and each contract counterparty (or group of counterparties) can negotiate to a mutually agreeable resolution. This indeed may be the win-win solution as the province lowers electricity costs, and project owners cut satisfactory deals.
Alternatively, the province potentially can pass legislation to implement blend and extend or to terminate the energy contracts. Theoretically, the province can extinguish the project owners’ right to compensation or replace their contractual right to compensation with a prescribed amount. As discussed in an earlier post, under the theory of parliamentary sovereignty, the traditional view is that the legislature can, with appropriately clear and specific wording, not only amend or terminate a contract, but also absolve the IESO or anyone else, from civil liability for those acts. The principle
behind parliamentary sovereignty is that the legislature is supreme, and the courts will not review the legislature’s policy choices.
Using legislation to extinguish civil liability is not without controversy. It offends a basic instinct of fairness: the IESO made a contractual commitment and should be bound by it. The province should not use legislation to get the IESO out of that commitment.
Legal scholars have also suggested that there may be a legal basis for challenging a legislature’s ability to amend contracts. Justice Patrick Monahan reasoned that the rule of law may be a restraint on the legislature’s right to private contracts. (Please see “Is the Pearson Airport Legislation Unconstitutional?: The Rule of Law as a Limit on Contract Repudiation by Government.”)
While legislation that extinguishes a private party’s contractual rights is rarely used, the Ford government has already demonstrated a willingness to use it to deliver on election promises. Shortly after being elected, the Ford government introduced legislation (White Pines Wind Project Termination Act, 2018, S.O. 2018, c. 10, Sched. 2.) that terminated Prince Edward County’s controversial White Pines Wind Project. This legislation extinguished the Crown’s and the IESO’s liability for damages that the project owner would have been entitled to for termination of its contract and replaced it instead with a formula for compensation prescribed in the legislation.
Whichever approach the IESO ultimately adopts, the IESO’s approach should encompass the effect that amendments to these energy contracts will have on those projects’ credit agreements and account for the corresponding amendments.
More generally, where the legislature amends or even attempts to amend a contract through legislation, it undermines the credibility of a government-backed agreement. Any project developer thinking of entering into a contract with the province or backstopped by the province will take note of the fact that that public body can change its mind at any time and get out of the contract without liability, and has done so.
As Ontario infrastructure projects take on a reputation of increased risk, costs of borrowing increase accordingly and even access to such capital might even be at risk. Ultimately, this makes all Ontario infrastructure project more expensive.
Overall, large gas, wind and solar generators across Ontario will be keen to see who the IESO selects to provide the independent analysis, and to see the report they produce.
Michael Killeavy is executive adviser with Power Advisory. As director, contract management at the OPA/IESO, Michael was responsible for the entire portfolio of OPA/IESO generation contracts as well as the energy support programs. Since joining Power Advisory in 2018 he has advised clients on commercial and market-related matters in Ontario. You can reach him at firstname.lastname@example.org.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on September 19, 2019
Climate change and how to combat it (or not) will likely be a key issue in this October’s federal election. Each of the six highest-polling political parties have put forth an environmental platform.
Generally, these platforms address the two leading sources of greenhouse gas output (GHGs): energy and transportation. They also acknowledge a tension between protecting the environment and boosting the economy and attempt to resolve it in various ways. The parties’ policies fall along an urgency spectrum of “do what we can” to reduce GHG emissions (with the exception of the People’s Party) to climate change is a “house on fire” crisis in Greta Thunberg’s words and we need to take radical measure to avert disaster.
In this two-part post, I review the environmental platforms of the People’s Party, Bloc Québécois, Conservative Party, Liberal Party, New Democratic Party and Green Party arranged from (in my view) least to most urgent. Each party’s climate change platform is polarizing depending on whether one believes a global crisis is imminent; whether Canada has a moral obligation to make specific reductions in GHG output or just to make reasonable efforts; and how much one is willing to give up to reduce one’s carbon footprint.
To put things in their scientific context, the 2018 Emissions Gap Report, published by the United Nations Environment Programme (UNEP), stated that while it is still currently possible to maintain global warming at below 1.5 to 2 degrees Celsius, it becomes less possible as time goes on and will become “extremely unlikely” if, by 2030, the gap between the required reduced level of GHG emissions and actual GHG emissions is not closed. (This is the gap referred to as the emissions gap).
To close the gap, global GHG emissions need to fall by 25 to 55 per cent by 2030. GHG emissions are actually trending in the wrong direction with global CO2 emissions increasing in 2017 after a three-year period of stability. Canada is the ninth highest emitter of GHGs in the world at 1.6 per cent, but among the top three emitters on a per capita basis.
To begin at the “least urgent” end of the spectrum, Maxine Bernier’s People’s Party is of the view that there is no scientific data supporting the conclusion that climate change is caused by human activity and that those who would say otherwise are alarmist and fear mongering. Under the People’s Party, Canada would withdraw from the Paris Agreement and largely abolish any green and environmental programs and incentives.
The Bloc Québécois’s environmental policies are comparatively thinner on detail than those of the other parties. The Bloc supports a carbon market and international agreements to restrict GHG output. It would provide tax incentives to support public transit and fuel-efficient vehicles and to convert heating oil to electricity (which only reduces GHGs where electricity is generated through renewable energy). However, without further details, it is difficult to fully assess the scope and degree of commitment by the Bloc to climate policies.
If one had to summarize the Conservative Party’s environmental and energy platform in two phrases, it would be: (1) getting the Trans Mountain expansion pipeline built, and (2) implementing environmental policies only where they also support the economic growth.
With respect to the Trans Mountain expansion, the Conservative Party has taken the aggressive pro-pipeline stance to preserve and develop jobs and investments in Canada’s oil and gas sector. Specifically, a Conservative majority would repeal Bill C-69. To recap, Bill C-69, which came into force this summer, overhauled the environmental assessment scheme of federally regulated projects.
Among its other features, the new Impact Assessment Agency’s scope of review is broader to include a project’s long-term environmental, health, social and economic impacts and its impacts on Indigenous peoples. This legislation also facilitates public and Indigenous participation. Conservative leaders in western Canada generally decried Bill C-69 as the “Anti-Pipeline Bill” and killer of the oil and gas sector. Similarly, a Conservative government would also repeal Liberal restrictions on oil tanker traffic along the British Columbia north Pacific coast.
Taking the opposite approach to Bill C-69, Andrew Scheer commits to facilitating approvals for major projects that are declared to be “for the general advantage of Canada.” A Conservative government would pass legislation that would clarify the roles of participants in consultations and the parties who may participate to only experts and those directly impacted. One may assume that this will circumscribe the scope of public participation.
The Conservative Party’s environmental platform is set out in its A Real Plan to Protect Our Environment. First, Scheer’s government would repeal the Liberal carbon tax and replace it with a legislated cap on GHG emissions of 40 kilotonnes (kt) of CO2 (which is 10 kt of CO2 less than under the carbon tax).
Emitters in excess of the cap would be required to invest in green technologies. Emitters below the cap, meaning households and most businesses, would not be subject to carbon tax levies.
The Conservatives also offer a basket of other policies to support the development of green technologies, such as programs to fund and facilitate home and building retrofits and establishing a $1 billion private-public venture capital fund.
Second, the Conservative Party also commits to review, study and update various current key environmental policies, such as those on protected areas, waterways, wetlands, air quality, invasive species and plastic waste, and to work with provinces, municipalities, Indigenous peoples, plastic producers, sector-specific groups and other parties, although A Real Plan does not commit to any specific outcomes.
Third, a Canada under Scheer’s leadership would focus on exporting green Canadian technology to other countries to help reduce foreign emissions. World leading green-tech Canadian companies would have access to favourable tax treatments and financing. The Conservative Party also proposes to launch a supporting “Canadian Clean” certification mark to identify green and clean products made in Canada.
While the Conservative Party’s platform acknowledges the importance of climate change, it has balanced the need to reduce GHG emissions with other economic goals. Generally, Canada under a Conservative government would only implement environmental policies where a case could also be made that that policy is a boon to the economy.
For those who view climate change as “do what we can” issue but not one that requires compromising other objectives, the Conservative approach may be ideal.
This is part one of a two-part series.
2019 Federal Election Campaigns Environmental/Energy Platforms
(September 25, 2019, 12:37 PM EDT) -- Climate change and how to combat it (or not) will likely be a key issue in October’s federal election. In the first part of this two-part series, I
examined how the People’s Party, the Bloc Québécois and the Conservatives are approaching the issue. In this final part, I will look at how the Liberals, the NDP and the Greens say they will approach climate change.
The incumbent Liberal government has implemented several hard-fought measures to combat climate change. Key among its achievements are the passage of the carbon tax, which levies a charge on individual and household output of GHGs; and the incentives for zero-emission vehicles, which offers a rebate of up to $5,000 per electric vehicle. Under a second Liberal mandate, single-use plastics, such as bags, straws, fast food containers and cutlery would be banned by as early as 2021.
Despite the controversy around the carbon tax, it may also be criticized for not going far
enough. Under the carbon tax, GHG emissions are priced at $20 per tonne rising to $50
per tonne by 2022. This is well below the price suggested by the United Nations
Environment Programme ‘s (UNEP) 2018 Emissions Gap Report of US$70 (approximately
$94) as instrumental in keeping global warming at less than 2 degrees Celsius.
The Liberal approach is a realpolitik one: steps are being taken to address climate change
with costs to Canadians, but these steps do not require radical sacrifices. Whether this
approach will be sufficient to avert climate change remains to be seen. (UNEP is of the
view that these steps will not be sufficient.)
A Canadian government formed by the New Democratic Party would declare a climate
emergency. Its platform sets out very specific commitments to combat climate change.
As prime minister, Jasmeet Singh would continue the Liberal carbon tax. An NDP government would set a goal of making Canadian electricity production net carbon free by 2030 (“net carbon free” means that any emissions are offset through other GHG reduction) and 100 per cent non-emitting by 2050. This is an extremely ambitious goal.
Over the last 15 years, Ontario eliminated coal-fired plants at great cost and expense, but
still maintains 28 per cent GHG-emitting generation. To replace fossil fuel dependent jobs, the NDP platform proposes to invest in green technologies, projecting that this will result in 300,000 new, green jobs.
By 2030, an NDP government would revise the National Building Code to require every
new building to be net zero. It would offer low-interest loans repayable through energy
savings to retrofit homes targeting all homes being net zero by 2050. The NDP vision is to
green Canada’s transportation sector by funding the expansion and modernization of public transit with electric vehicles, lower fares, more rail and bus links and more bike paths. Households that purchase an electric vehicle would receive a $15,000 rebate.
The NDP environmental platform puts forth a large-scale overhaul of energy, transportation and housing with significant reductions to GHG emissions. To estimate to the scope of this, one might draw inferences from the cost of the Green Energy Act in Ontario which transitioned the energy supply-mix to renewables and conservation measures. In 2015, the Ontario auditor general reported that Ontario electricity consumers paid an additional $37 billion from 2006 to 2014, and would pay an additional $133 billion from 2015 to 2032. For those who view climate change as a crisis and are willing to pay a cost to averting it, the NDP approach may well be appealing.
The Green Party proposes the most specific, comprehensive and ambitious environmental and energy reform: The Green Party would declare a climate emergency. It would implement policies that would reduce GHG emissions by 60 per cent against 2005 levels by 2030 and to zero by 2050. To achieve this extremely ambitious and costly goal, the Green Party pledges to radically reform energy, transportation and the economy. It would be a cross-party effort with the establishment of an “inner cabinet” modelled on Winston Churchill’s wartime cabinet, with the enemy in this case being climate change.
A fee will be levied on CO2 emissions, the proceeds of which will be returned to Canadians in the form of dividends. Fracking would be immediately banned, bitumen production phased out between 2030 and 2035 and by 2030, all electricity produced in Canada would be from renewable sources supported by a revitalized national electricity grid. The National Building Code will be revised to require every new building to be net zero by 2030, and energy efficiency retrofits to existing buildings will be subsidized. Sales of new internal combustion engine cars will be banned by 2030. The rail network will be expanded, and high-speed rail will be built among major Canadian cities.
Elizabeth May compares the current threat of climate change to that faced by the Allies in the Second World War. And indeed the Green Party’s platform is a radical and costly
overhaul of how Canadians live and get around to reduce our carbon footprint and avoid
climate change catastrophe. The Green Party’s environmental policies make perfect sense in the context of a war against climate change: no cost is too great to avert catastrophe.
October’s federal election is one of the few remaining opportunities to determine how
Canada will respond to climate change before 2030. The Green Party, NDP, Liberal Party,
Conservative Party, Bloc and People’s Party each put forth a policy based on different views of climate change.
As a voter, one’s assessment of these platforms may come down to how closely a party’s
sense of urgency aligns with one’s understanding of climate change, and one’s views on
the appropriate means to fight climate change and the role Canada should play in the
Weighing the various platforms is made more difficult by the fact that there is no
guarantee that a party’s proposed policies will actually avert a climate change crisis. Given
the possible magnitude of our choice, this election is definitely one where Canadians
should make an active, considered decision as to where we stand on climate change.
This is part two of a two-part series. Part one: Where federal parties stand on climate
On Monday, General Motors Canada announced that, by December 2019, it would be closing its 100-year-old auto manufacturing facility in Oshawa, Ontario, and laying off approximately 3,000 employees. This closure will cut deeply into the economies of Oshawa and Ontario. Oshawa willnot only lose thousands of jobs from its largest employer, but also a number of other jobs directly dependent on the manufacturer’s presence (the Ontario Federation of Labour multiplier estimates nine non-GM jobs lost for each GM job). .
A variety of factors are being blamed for the shut down: (a) American protectionism: approximately 90% of the cars produced at the Oshawa plant are exported into the United States. Uncertainty around American tariffs on cars manufactured outside of the U.S. under the new United States-Mexico-Canada Agreement incentivized General Motors Company (GM) to reduce manufacturing outside the U.S.; (b) Canadian environmental policies: the recently-enacted Canadian federal carbon tax will drive up manufacturing costs; and/or (c) changes in consumer preferences: consumer demand for large sedans, like the Chevy Impala and Cadillac XTS models made at the Oshawa facility, is declining. The Oshawa facility has been operating at less than half capacity for the last few years.
GM itself has described these closures as part of a global transformation strategy to move away from large, GHG-emitting vehicles towards electric and autonomous cars and to use technology to better streamline production. GM contemporaneously announced the closure of four other plants in Michigan, Ohio and Maryland, and three more outside of North America. The closures will result in the laying off of 15% of GM employees with expected savings of $6 billion by 2020.
GM’s CEO Mary Barra stated that, “we are in the midst of a transportation revolution”, and that GM envisions a near future where all cars are electric, self-driving and interconnected – a future of “zero emissions, zero crashes and zero congestion”. In the next four to five years, GM announced intentions to offer 20 different models of electric cars. Like GM, other car manufacturers have similar projects underway that focus on electric and self-driving cars.
The political response to the GM closures has been mixed. There have also been calls for political leaders to look for ways to induce or force GM to maintain the status quo. The day after GM made its announcement, President Trump tweeted about the facility closures in the United States: “Very disappointed with General Motors and their CEO, Mary Barra, for closing plants in Ohio, Michigan and Maryland…..We are now looking at cutting all @GM subsidies, including for electric cars.” In Ontario, Premier Doug Ford cited the plant closure as an example of the federal carbon levy [*pls link to my article] driving up manufacturing costs and killing jobs. He called on the federal government to repeal the tax. The federal reaction was more accepting of the closure, with Prime Minister Trudeau tweeting disappointment and a note that Ottawa would help affected families “get back on their feet”.
If we are, as Mary Barra says, in the midst of a revolution in the auto sector, then now is a critical time for policy leadership in response to this titanic shift. There are going to be many different policy challenges that both the federal and provincial governments will need to address. Canada’s transportation infrastructure will need an extensive charging infrastructure to support the anticipated wave of electric vehicles. On the flip side, an all electric future will eliminate the need for gas stations, and we will need to consider how gas stations and the gas supply chain should be repurposed. Autonomous, self-driving vehicles will eliminate much of the need for parking which will free up central real estate for other uses. Most important, however, Ottawa and Queen’s Park need to consider and address head on how it will respond to jobs lost to automation and changes in technology.
If GM is right, then there are seismic changes on the horizon for the auto sector, and consequently on our economy and society. The right policies and incentives will be critical in preparing the Canadian economy for the future.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on November 5, 2018.
In the 2015 Paris Agreement, Canada committed to take steps to maintain global warming at no more than two degrees Celsius than pre-industrial levels, and to aim for a target of 1.5C. As a result, the federal government and the provinces in consultation with First Nations developed the Pan-Canadian Framework on Clean Growth and Climate Change to, among other things, price and reduce carbon emissions.
A key component of Canada’s GHG emissions reduction plan is the Greenhouse Gas Pollution Pricing Act (better known as the federal carbon levy or the carbon tax or the federal backstop) which received royal assent in June 2018. This act puts a price on carbon — specifically $20 per tonne in 2019, rising by $10 per tonne to $50 per tonne in 2022.
To give some context, burning one litre of gasoline produces 2.3 kilograms of carbon dioxide. Using an 80-litre tank of gas produces approximately 184 kg of carbon emissions. To put it another way, every 5.5 times one fills up one’s tanks of gas, one has produced about a tonne of carbon dioxide. (The reason why the carbon emission produced weighs more than the gasoline that produced it is that during combustion the carbon in the gasoline combines with oxygen in the air to produce carbon dioxide. The additional weight comes from the oxygen molecules.) A tree processes a fraction of that: one tree absorbs about 21.8 kg of carbon dioxide per year.
The federal carbon levy is a “backstop”: it applies only in those provinces that have not implemented their own comparable system for pricing carbon. In late October, Prime Minister Trudeau announced that the federal carbon levy would apply in Ontario, Manitoba, New Brunswick, Saskatchewan, Yukon and Nunavut beginning in 2019. (Several provinces are challenging the constitutional validity of the federal carbon levy. This issue remains to be determined by the courts, although general thinking appears to be that the federal carbon levy act does fall within federal jurisdiction and is validly enacted.)
The principle underlying the federal carbon levy is “polluter pays” in that the person or organization producing the carbon pays for preventing or managing the environmental, health and social costs of pollution, instead of socializing the costs of greenhouse gas emissions and resulting climate change.
The basic mechanics of the federal carbon levy is a charge that is imposed in one of two ways.
Fossil fuel charge: The first way is a per unit charge on fossil fuels, which includes gasoline, natural gas, propane and coal, among other things. For example, the levy on gasoline will be $ 0.0442 per litre beginning on April 1, 2019, and rising to $0.1105 per litre by March, 2022. The levy on an 80-litre tank will be $3.54 rising to $8.84. The levy is to be paid by fossil fuel producers and distributors. End-use consumers will not be directly responsible for paying the charge, but we can expect that those additional costs will be passed on by distributors and producers to consumers. There are special rules for fuel used in international commercial transportation, as well as for specific activities like farming.
Output-based pricing for certain covered industries: The second method is the output-based pricing system (OBPS). The policy reason for creating this separate second method is to encourage specifically prescribed, emission-intensive industries (including electricity generation using fossil fuels, auto manufacturing, processing of certain foods, pulp and paper production, chemical production, oil and gas processing, iron and steel production and many other industrial processes) to reduce GHG emissions, while at the same time ensuring that the compliance costs do not hurt market share and competitiveness. The federal government has indicated that it may prescribe additional industries in the future.
Within these covered industries, the OBPS method applies only to producers that emit over 50,000 tonnes of greenhouse gases per year. (Producers that emit between 10,000 and 50,000 tonnes per year are expected to have the option of opting in to the OBPS beginning in 2020.) Fuel for facilities that are part of the OBPS is exempted from the fuel charge. The federal government expects that the OBPS will apply to approximately 133 facilities in backstop jurisdictions.
The federal government will set a GHG emission standard per production unit benchmarked to the national average emission intensity. For example, for pulp and paper producers, there will be a standard CO2 emissions per tonne of finished product. The emission intensity standard is expected to be set at 80 per cent of the national average emissions intensity (i.e., 20 per cent less than the average emissions intensity).
The government has indicated that it would adjust this percentage in light of in specific cases. For example, the cement, iron and steel, lime and nitrogen fertilizer industries were determined to be trade-exposed, and so this standard was relaxed to 90 per cent of the national average emissions intensity to maintain competitiveness. The expectation is that the emission intensity standard will become more stringent over time.
Each OBPS-registered producer will have an annual emission limit calculated based on the emission intensity standard and their total production. Producers that emit more than the standard emission intensity will be required to either pay the carbon charge ($20 per tonne in 2019 increasing to $50 per tonne in 2022) or to submit surplus compliance credits or offset credits to cover their excess emissions. Conversely, producers that emit less than their calculated annual emission limit will receive credits that they can sell or trade.
The federal government has committed that proceeds from the federal carbon levy will be given back to residents of the province in which they were collected in the form of rebates, incentives and investments in GHG-reducing technologies and infrastructure.
The federal carbon levy takes effect in 2019. Administratively, there is a lot of work to do over the next few months. Producers and distributors are required to register with the minister of national revenue. Covered facilities are required to register with Environment and Climate Change Canada and prepare compliance reports.
Detailed requirements on how emissions will be quantified and verified need to be developed, and the service providers need to make such services available. A system for tracking, managing and trading compliance credits needs to be developed.
There is a constitutional challenge on the validity of the legislation to be survived. Things will move fast over the next few months. Producers, distributors, emitters and industries should be prepared to respond quickly to ensure that they know how this new regime works and have met their compliance obligations and are taking full advantage of its opportunities.
The new carbon pricing environment also opens up new opportunities and reasons to invest in clean tech, reduce compliance costs, manage GHG output and perhaps even have a net benefit.
We will stay on top of new developments and keep you posted.
The Greenhouse Gas Pollution Pricing Act puts a price on GHG emissions.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on September 28, 2018.
Bill 34, the Green Energy Repeal Act, received most of its attention as the bill that would undo the Green Energy Act. Importantly, however, this bill also contains provisions indicating the new government’s policy direction for energy conservation and demand management (CDM). In this article, I briefly outline the history of conservation in Ontario, where we are now and what conservation might look like under Bill 34.
History of conservation in Ontario
Historically, energy conservation policies existed to varying extents under Ontario Hydro, but it remained less important than generation when it came to determining how the province would be powered.
In 2011, Ontario launched the 2011-2014 CDM Program, a large scale, comprehensive province-wide energy conservation and demand management program. It was a significant achievement as one of the first large-scale, comprehensive conservation programs in the world mandated to achieve significant reductions in electricity consumption.
This program offered incentives to homeowners, businesses and large industrials to take measures to reduce their energy consumption, such as replacing incandescent light bulbs with CFL or LED bulbs or shifting their energy consumption to times when there was more surplus electricity available. The consumer programs were marketed under the “saveONenergy” brand. Some of these programs built on former Ontario Hydro programs or existing local distribution company programs.
The province implemented the 2011-2014 CDM Program through the Ontario Power Authority (OPA, now the Independent Electricity System Operator or IESO) working together with local utilities. These programs were funded through the electricity rates.
After 2014, the ministry again directed the OPA to renew, improve and re-launch CDM in the form of Conservation First, delivered by the local distribution companies and funded by the OPA, again through electricity rates. The title, Conservation First” indicated that conservation was the first resource that the province should turn to for its energy needs as the one that was least costly and most efficient to implement. These CDM policies and others like it were cornerstones of the Green Energy policy.
What conservation has accomplished
The IESO has recently reported on the success of Conservation First and earlier CDM programs citing the fact that since 2006, “Ontarians have saved more than 68 billion kilowatt-hours through their conservation and energy-efficiency efforts — about the same amount as Toronto-area customers would consume in two and a half years.” (Power Perspectives, Today’s Challenges, Tomorrow’s Opportunities, 2018, published by the IESO.)
Under the terms of its original direction from the government, Conservation First comes to an end in 2020. In Bill 34, Premier’s Ford’s government is signalling what the next iteration of CDM policy in Ontario might look like.
Part II.3 of Bill 34 contains the provisions that authorize the lieutenant governor to make regulations creating energy conservation permissions and requirements for and on individuals, businesses and the public sector in Ontario, some of which have similarities with the to-be-revoked regulations under the Green Energy Act. While exactly whom this bill would affect, what they would need to do and how much efficiency would be achieved will be in the regulations, this bill does set up the framework for future CDM policies. The authorizing provisions include:
We will continue to monitor the progress of this bill and any regulations that may be made under it.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on August 29, 2018.
In a decision released on Aug. 27, Tesla scored a significant victory over the new Ontario government. The court quashed and set aside the province’s “unlawful exercises of discretion” contained in its announced wind-down of Ontario’s subsidies program for electric vehicle purchases — a wind down from which only Tesla and its customers had been excluded.
One fallout from the nixing of Ontario’s cap-and-trade program was the resulting cancellation of greenhouse-gas reduction programs funded by cap-and-trade proceeds, like the Electric and Hydrogen Vehicle Incentive Program (the EV Incentive Program). The EV Incentive Program offered incentives of up to $14,000 to purchasers of electric vehicles in Ontario.
On July 11, 2018, the Ministry of Transportation announced that the province would be terminating the EV Incentive Program, winding it down over the following two months. The Ministry also announced that the incentive would still be eligible: (i) to purchasers who had received their cars by July 11, 2018, and (ii) for any inventory that dealers had on hand or on order, as long as it was delivered to purchasers by Sept. 10, 2018.
Shortly after making the public announcement, the province sent a separate letter to Tesla, advising the company that it alone (among some 17 vehicle manufacturers who produced cars eligible for the EV Incentive Program) would not be eligible for further incentives during the wind-down period, as the exemptions applied only to “franchised dealerships.” (Tesla’s dealerships are wholly owned by the U.S. manufacturer, instead of being franchised.)
Court application and decision
On Aug.10, 2018, Tesla brought an urgent application to the Ontario Superior Court of Justice, seeking to quash the province’s decision to exclude Tesla from the wind-down period exemptions.
Why was Tesla singled out for exclusion? In the application, the company alleged that the province was targeting Tesla for inappropriate and purely political reasons, including that Tesla is viewed as a luxury car brand. Tesla also alleged that the current government viewed the EV Incentive Program as a political “favour” to Tesla granted by the previous government, which the new government wished to undo. These allegations were based on comments made by a parliamentary assistant in the legislature and in an interview with Premier Doug Ford.
The government’s witness in the court application stated that the purpose of extending the winddown exemptions only to franchised dealerships was to protect small and medium-sized “independently-owned” businesses who would otherwise be stuck with excess inventory ordered with the expectation of increased sales generated by the subsidies. However, the court found that this stated rationale was not supported by any evidence, which demonstrated that in fact a number of dealerships were owned by large businesses.
In granting Tesla’s application, the court noted that courts will not review pure policy decisions.
decisions made by elected representatives are assumed to reflect the will of the people, and a court has no business interfering with the exercise of that will (with the proper check on such exercise being the opportunity to replace representatives in the next election).
However, the court distinguished between core policy decisions and administrative decisions made in the course of implementing those core policy decisions (which a court can and does review.) The example cited in the decision is that a court cannot tell the government that it must fund or not fund a specific project, but it can tell the government whether a payment or withholding of a payment was improper or unlawful under a statute or regulation. The court held that when the legislature cancelled the cap-and trade program, this was clearly a policy decision, as was the decision to offer the winddown period.
However, the court further held that when the cabinet designed the terms of the wind-down period to exclude Tesla, its role changed from one of the maker of core policy decisions to the administrator of executive programs, rendering it subject to judicial review. It was also a factor that cabinet’s decision specifically targeted Tesla.
Satisfied that the decision to exclude Tesla from the wind-down period was an administrative decision, the court undertook a review of whether it had been made for an improper purpose, and determined that it had been. The court cited the facts that: (i) the government had targeted Tesla; (ii) targeting Tesla had no relation to cabinet’s stated goal of minimizing losses to small and midsized dealerships; (iii) the government appeared to revise the terms of the wind-down program specifically to ensure they would exclude Tesla; and (iv) the government did not give Tesla the opportunity to be heard.
Tesla had asked the court to set aside the condition of the wind-down that limited its application to franchised dealers, allowing Tesla to participate. The court declined to do so, finding that it would be improper for the court to order the government to fund subsidies to Tesla customers. The court did however quash and set aside the wind-down program as announced (presumably to be amended and reinstated by the province in a manner that will withstand judicial scrutiny).
Tesla v. Ontario is the latest case to explore the thorny legal issue of when a government action constitutes a policy decision (that a court will not review) and an administrative decision (that a court will). That line often resists clear delineation. This case does appear to indicate that to be a core policy decision a decision should ideally be a high-level setting of a political direction and apply generally — it should not single out specific individuals or companies. It is not yet clear whether the province will seek leave to appeal the decision to the Court of Appeal, and it has 15 days to do so.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on June 25, 2018.
On July 16, 2018, the Ontario government tabled Bill 2, the Urgent Priorities Act. This bill targets two energy companies to cause two very specific actions: 1) To give the province significant authority over executive compensation at Hydro One; and 2) To terminate the White Pines Wind Project. (The third part of the bill relates to ending the strike at York University which I do not discuss in this article.)
Executive compensation at Hydro One
Following the resignation of Mayo Schmidt, the CEO of Hydro One, and the board of Hydro One, the Hydro One Accountability Act would give the province significant authority over executive compensation until Jan. 1, 2023. It requires Hydro One to consult with the province and its five major shareholders in establishing the executive compensation framework, which then requires approval from the management board of cabinet to take effect.
The management board of cabinet would now have the power to direct Hydro One as to the process and content of the framework, including capping compensation payable. Finally, the Act specifies that executive compensation cannot be charged to electricity ratepayers. It will need to come out of some other revenue source.
The section then goes on to absolve the Crown and Hydro One from any liability that may arise as a result of this Act, including under any securities laws or as a result in any decreases in Hydro One’s share price. The section also bars the enforcement of any foreign judgments or orders that might be brought by investors outside Ontario.
At the time of Hydro One’s privatization, it was conceived of as a private entity which would not be used to implement policy. In fact, the province and Hydro One entered into a governance agreement to ensure that the province stayed in its role as shareholder and did not try use its majority shareholding to implement policy.
This bill is significant because it signals a willingness on the part of the government to use its legislative powers to intervene in the internal affairs of a large Ontario infrastructure company that is privately governed. Depending on how much one is willing to read into this bill as representative of the government’s views generally, this government may be of the view that large infrastructure companies that have a significant impact on the public should be more subject to regulation and oversight.
Termination of the White Pines Wind Project
The White Pines Wind Project was originally planned to be a wind farm made up of 27 wind turbines in Prince Edward County. The project has been underway since 2010, when it received one of the first Feed-in Tariff contracts (FIT contract) in which the Ontario Power Authority (now the Independent Electricity System Operator or IESO) agreed to purchase the power produced at a set prices. The wind farm faced significant opposition from local residents and the project was scaled down to nine turbines. Just prior to the election, the project received permission from the IESO to commence construction. The project was owned by wpd Canada which is a subsidiary of wpd Europe, headquartered in Germany.
The White Pines Wind Project Termination Act, 2018 terminated this project’s FIT contract and revoked its permits and approvals retroactive to July 10, 2018. The legislation also deemed terminated the agreement between the IESO and the project lender, in which the IESO acknowledged the lender’s right to take over the FIT contract if wpd Canada defaulted on its borrowing obligations. The legislation went on to require wpd Canada to decommission the project and return the land to its original state.
Significantly, the bill then legislates away wpd Canada’s rights to compensation under contract law, replacing it that with the amount prescribed in the bill. The prescribed compensation amount is essentially (i) its costs plus (ii) its break-fees to its lenders minus (iii) the value of its assets. (There is some discretion for the lieutenant-governor to adjust or cap the amount.)
As with the Hydro One Accountability Act, the bill then goes to great lengths to extinguish any kind of liability on the Crown or the IESO. Under the theory of parliamentary sovereignty, the traditional view is that the legislature can, with appropriately clear and specific wording, not only terminate a contract, but also absolve the Crown or anyone else, from liability for that termination. The principle behind parliamentary sovereignty is that the legislature is supreme, and the courts do not see their role as second-guessing the legislature’s policy choices.
The clear message here is that the government is going to use legislation as a blunt instrument to deliver on its election promises — even if that means overriding a private party’s contractual rights. While the government has always had the right and the ability to do so and has done so in the past, this power has been used with restraint. (By way of comparison, when the Ontario Power Authority cancelled two contracts to build gas plants in Oakville and Mississauga in 2010 and 2011, the legislature did not legislate away the province’s liability to the counterparties for damages under contract law.)
Where the legislature amends a contract through legislation, it undermines the credibility of a government contract: Anyone thinking of entering into a contract with a public body will take note of the fact that that public body can change its mind at any time and get out of the contract without liability. White Pines is an example of the tension between the desires of the public as expressed in an election versus private contractual rights. We are seeing a new government that is much more willing to push the boundaries and come down on the side of the electorate’s desires.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on June 18, 2018.
Before he was elected, Ontario’s premier-designate Doug Ford published his vision for Ontario, “For the People, A Plan For Ontario,” and the portion that relates to energy can be divided into five main promises:
1) Fire the board and CEO of Hydro One, and reduce the salaries of Hydro One and Ontario Power Generation (OPG) executives;
2) Repeal the Green Energy Act (Ontario), cancel energy contracts that are in the pre-construction phase, re-negotiate other energy contracts and declare a moratorium on new ones;
3) Move the costs of conservation programs to the tax base and out of the electricity rate base;
4) Stabilize industrial electricity rates through aggressive reforms; and,
5) Do away with the new cap-and-trade regime and any regime for pricing carbon emissions in Ontario.
I dealt with part one of this two-part series in “Doug Ford vs. Hydro One brass.” I will address the others here.
As I noted in an “The Ontario election: possible impact on energy projects,” a new government has the unfettered ability to repeal policy implemented by a previous government. Theoretically, therefore, there is nothing preventing a Conservative majority from repealing the Green Energy Act (Ontario). Many of the later energy contracts — including the Feed-in Tariff Contracts and the Large Renewable Procurement with the Ontario Power Authority (now the Independent Electricity System Operator, or IESO) — give the provincial entity the right to terminate those contracts upon payment of a termination fee.
It is more interesting to consider how a new government might seek to reopen earlier, existing energy contracts.
Where a provincially created entity like the IESO has entered into a contract, those contract terms are legally binding on that entity, just like they would be on any other commercial party. It would be a breach of contract if the provincial entity were to try unilaterally to alter any of those contractual terms and doing so could make the provincial entity liable for breach of contract.
If the province seeks to renegotiate the contract price of some of the renewable energy contracts, the province will need to get the counterparties to the table, which is typically done by offering the counterparty some sort of inducement. In such a case, any reduction in the contract price would need to be offset by some other equally attractive benefit to the project developer.
How would the costs of conservation be moved to the tax base?
Conservation and demand management programs are now largely funded through electricity rates. A Plan for Ontario estimates this cost at $433 million per year. Ford has indicated that these costs would now be taken out of the electricity rate base and paid for through the tax base.
This policy change has been relatively uncontroversial and is essentially just a shift from one public revenue base to another largely overlapping base. Because the tax base is tiered based on income, the shift will result in reducing the burden of conservation costs on those with lower incomes and shifting it to those with higher incomes.
How would industrial electricity rates be stabilized through aggressive reforms?
The PC party has provided little guidance on what reforms are contemplated and how industrial rates might be impacted. We will need to wait until the new government specifies exactly what it intends to do.
Can the new government do away with carbon pricing in Ontario?
Beginning on Jan. 1, 2017 Ontario implemented a cap-and-trade program on greenhouse gas emissions (GHGs). Under that program, the tonnes of GHGs that businesses and industrials can emit is capped by regulation, and a market was created in which allowances can be traded by emitters who either have spare allowances or need more. Part of Ford’s plan includes scrapping the cap-and-trade program in its entirety. In place of carbon pricing, the PC platform contemplates a fund to invest in emissions reduction technologies in Ontario.
As noted above, a new government is free to repeal any act implemented by a prior government under the doctrine of parliamentary sovereignty. However, if Ontario’s cap-and-trade program were to be repealed, the backstop federal carbon-pricing program under the proposed federal Greenhouse Gas Pollution Pricing Act would take its place.
The federal government sets minimum standards for a provincial carbon reduction program. For carbon-pricing systems, this includes a set price of $10 per tonne in 2018 rising to $50 per tonne in 2022. For cap-and-trade systems, it sets: (i) a 2030 emissions-reduction target of at least 30 per cent, and (ii) increasingly stringent emission caps to at least 2022. Where a province does not meet the minimum standard (by, for example, having no carbon regime), the federal carbon-pricing system would take effect.
Ford has indicated that he would challenge the federal government’s ability to impose its carbon-pricing system in Ontario. While a detailed review of the likelihood of the success of such a constitutional challenge is outside the scope of this article, the basis of it would likely be a division of powers argument: the pith and substance of imposing a carbon-pricing scheme on the provinces does not fall within one of the heads of power granted to the federal government under the Constitution Act, while the federal government would argue that it does.
Ford and the new PC majority have a tremendous ability to reshape the energy market in Ontario and appear highly motivated to do so. With respect to his specific promises, some may be immediately achievable.
Others may need to be determined by the courts, through significant negotiations with contract counterparties, or are still subject to further consideration as the new government takes shape. One thing is certain: the energy market in Ontario will need to ready to deal with the prospect of fundamental change for the first time in a long while.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on June 11, 2018.
On June 7, Doug Ford received a strong mandate from Ontario voters to implement his vision for the province.
The portion of that vision that relates to energy — outlined in the Progressive Conservative Party’s “For the People, A Plan for Ontario” released just before the election — can be divided into five main promises:
(1) Fire the board and CEO of Hydro One, and reduce the salaries of Hydro One and Ontario Power Generation (OPG) executives;
(2) Repeal the Green Energy Act (Ontario); cancel energy contracts that are in the pre-construction phase; renegotiate other energy contracts; and declare a moratorium on new ones;
(3) Move the costs of conservation programs to the tax base and out of the electricity rate base;
(4) Stabilize industrial electricity rates through aggressive reforms; and,
(5) Do away with the new cap-and-trade regime and any regime for pricing carbon emissions in Ontario.
Now that Ford is premier-designate, how might he deliver on these promises when he takes office on June 29? In this first of two parts I will look at Ford’s plans for Hydro One. I will address the others in part two.
Can Ford fire the board and CEO of Hydro One?
When Ontario Premier Kathleen Wynne announced in the fall of 2015 that the province would sell up to 60 per cent of Hydro One, it was highly controversial. And it remains a political lightning rod today.
The sale was completed in three tranches (the last of which took place in May 2017). It raised over $9 billion in proceeds to pay for provincial infrastructure projects and to reduce provincial debt. The province now owns just under 50 per cent of the shares in Hydro One with the balance held by private investors, including investment funds, First Nations and OPG.
Hydro One is incorporated under the Ontario Business Corporations Act and is governed by that Act and the Electricity Act (Ontario). Hydro One also has a governance agreement in place with the province that, among other things, is intended to ensure that the province sticks to its role as shareholder and does not interfere in Hydro One’s management or seek to implement policy through its majority shareholding.
The board alone is responsible for the management and affairs of Hydro One. Under the governance agreement, the province may nominate up to 40 per cent of the directors. Once on the board, however, the directors must act with a view to the best interests of Hydro One (and not of any one particular shareholder). Whether the level of compensation Hydro One pays its directors, CEO, executives and employees is necessary to attract the best talent and whether doing so is in the best interest of Hydro One are fact-specific questions that the board will need to wrestle with and ultimately determine.
The province does have the ability to trigger the removal of the full board under the governance agreement, excluding the CEO. The province may do so by notifying Hydro One that it is calling a shareholder meeting to remove the directors. The province could then nominate replacement directors who it believes would be inclined to lower levels of executive compensation and salaries. But what the board cannot do is take directions from a shareholder, even if that shareholder nominated and elected its members.
Accordingly, while the province does have some indirect ability to influence compensation levels and to shape the constitution of the board, it does not have the ability to do anything so direct as set salaries or fire the CEO.
This article originally appeared on The Lawyer’s Daily website published by LexisNexis Canada Inc. on Tuesday May 29, 2018.
As was the case in the last two Ontario provincial elections, energy policy is again a central issue in 2018.
The incumbent Liberals pledge to stay the course on a green, low carbon economy, with over $4 billion in proposed carbon market investments.
The PC Party has indicated it intends to make sweeping changes, including: (i) repealing the Green Energy and Green Economy Act (Ontario) and the cap-and-trade program (and even possibly challenging the federal regime that would take its place), and (ii) declaring a moratorium on new energy contracts or even cancelling existing contracts where construction has not yet begun.
The NDP promises to continue with a renewables policy and a carbon pricing program. Andrea Horwath has also indicated that, if elected, the NDP would buy back Hydro One.
Over the past 15 years, Ontario energy policy has focused on renewable energy, conservation and demand management and the reduction of greenhouse gas emissions. Some policies, like time-of-use pricing, are open to all households and small businesses who adjust their consumption to take advantage of it. The Industrial Conservation Initiative is also open to all qualifying large and certain other qualifying electricity consumers; by reducing their consumption during peak periods, they receive a discount off their electricity bill.
In other policy instruments, the province has directed the Independent Electricity System Operator (IESO, formerly the Ontario Power Authority) to enter into contracts with private counterparties to build energy projects, primarily renewable. Under these contracts, the IESO provides payments to a project, typically supporting project revenues over a long-term period, typically 20 years.
Doug Ford’s statements about the potential reverses in energy policy have quite understandably caused uncertainty: can the government take away an energy program or renege on a contractual commitment?
Generally speaking, a government has the freedom to change course on policy implemented by a previous government or by itself. It can also amend or repeal any currently in force legislation. Under the doctrine of parliamentary sovereignty, a government is free to legislate as it chooses subject only to constitutional limitations. Further, without specifically changing policy, a government can dramatically alter the effectiveness of a program by increasing or reducing its funding.
That said, where a provincially created entity like the IESO has entered into a contract, and where the government makes a policy change that results in that entity terminating that contract, that entity can, like any other commercial party, be liable for breach of contract and damages. Whether a contract has been breached and damages have been suffered is a context-specific analysis that would have to be determined in accordance with that contract’s terms.
Energy contracts in Ontario contain terms that are particularly relevant to a government looking to make changes in energy policy:
It is most likely that if a new government terminates or amends any power contracts, it will take place using the mechanisms of one or both of these types of provisions.
It should be noted that, even if a project developer would be entitled to damages for breach of contract by a statutory entity, the legislature does have authority to “legislate away” such payments. With required “clear and specific language,” the legislature can not only cancel a contract, but absolve itself or any of its entities of liability for breach.
As a practical matter, however, such a step would need to be weighed against the message it would send to project developers and their lenders that provincial contracts may not be as “iron clad” as generally thought. In the long run, developers and lenders would be deterred from investing in provincial infrastructure or would demand higher returns for doing so. Such a move could lead to higher electricity prices or generally higher costs of capital for the province in the long run.
Until the results of the election are known and campaign platforms become policy, it is impossible to predict what specific changes might be made to Ontario’s electricity market. However, one thing that is certain is that participants in the energy market — and their counsel — will be eagerly monitoring the June 7 results.
Policy makers federally and in Ontario view the development of smart grids as an essential part of Canada’s future, clean low carbon infrastructure and economy. Budget 2017 (Canada) indicated that $820 million in funding would go towards green infrastructure projects, including an NRCan program for developing smart grids. Ontario’s 2017 Long Term Energy Plan included among future policy goals that the Province would continue to build on smart meters and invest further in smart grids.
These policy statements are being implemented through the Ontario Minister of Energy’s October 25, 2017 directive to the Ontario Energy Board which contained a mandate to examine opportunities for smart grids, as did the directive to the Independent Electricity System Operator (IESO) of the same date. The IESO’s Putting Ontario’s Long Term Energy Plan into Action (January 2018) stated that the IESO will seek renewable distributed energy resource (DER) projects that work with smart grid and other technologies.
A smart grid is a system of distributing electricity (a grid) that is able to sense and then to respond dynamically to load, generation and other grid events. A grid is “smart” because it is equipped with technology that allows for two-way digital communication among grid users, such as smart meters and other advanced metering infrastructures, and with automated systems that give the grid the ability to respond to the information it receives, such as smart inverters, DER Management Systems (DERMS) and advanced distribution management systems (ADMS). By connecting a generation or energy storage asset, a smart grid can do more to balance generation and load and to provide other services for grid stability and regulation.
Policy makers’ focus on smart grids makes a lot of sense and the benefits of evolving the current systems into smart grids appear to be enormous:
Asset Use and Efficiency – a smart grid makes more efficient use of the existing assets. For example, on a bright sunny day a smart grid will choose solar power as the power source to meet local demand instead of a power source that relies on more costly, GHG-emitting fossil fuels, like a gas plant. Or a smart grid might dispatch on a local power source to meet local needs and so reduce line losses and system wear. Meeting local demand through local generation has an additional benefit to the electricity system in that it reduces congestion on the Province-wide transmission system. Generally, by making better use of energy resources, smart grids are expected to reduce the costs of providing electricity and therefore consumer costs.
Increased Penetration of Renewables and Reduced GHG Emissions – As in the above example where a smart grid calls on a solar farm to provide electricity on a sunny day, smart grids are generally anticipated to make more efficient use of renewables (such as solar, wind and hydro) and storage technologies. A smart grid will first dispatch renewables where they are able to generate in lieu of a power source that emits GHGs. Renewable power becomes more economical and GHGs are reduced.
Reliability – A smart grid has the ability to sense and to respond dynamically to incidents and to manage bidirectional power flow over the grid. For example, a smart grid will be able to balance supply and demand by working with local load and generation. This ability is expected to improve the quality of the power delivered to consumers, and is also anticipated to allow a smart grid to recover from incidents more quickly and generally to reduce outages.
Encouraging Prosumers – A prosumer is an electricity consumer who also produces electricity. The classic prosumer example is a homeowner who also generates electricity through rooftop solar panels. In order to develop a market for prosumers, the electricity system needs to have the required “smart” infrastructure in place, such as meters that allow the prosumer to sell electricity back into the grid, and an information system that gives prosumers real-time price signals. A smart grid will provide much of the supporting infrastructure to transform consumers into prosumers.
The EDA and the Role of the LDCs - The Electricity Distributors Association (EDA) has mapped out a vision for smart grids in Ontario in the EDA’s February 2017 publication, The Power to Connect. Local distribution companies (LDCs) are well positioned to develop smart grids for their service territory. In this model, a local smart grid becomes a vibrant market where consumers, large and small generators, the IESO and other third parties work together to deliver electricity in the most efficient and stable way as enabled by the LDCs. The EDA has called for a regulatory environment that will encourage LDCs to invest in smart grid enabling infrastructure and assets.
At the same time, a wide-spread rise of smart grids will also create challenges:
Cybersecurity – As electricity grids become increasingly digitized and automated, they also become more vulnerable to cyber risks, attacks and privacy breaches. Hand-in-hand with the development of smart grids, cyber security technologies, practices, policies and training will also need to advance to ensure their secure operation and risk mitigation.
Stranded Assets – One of the benefits of the smart grid is also one of its drawbacks. An efficiently operating smart grid means that electricity consumers will rely less on existing infrastructure and assets or will use them differently. For example, instead of needing a constant supply of electricity from the Province-wide grid, a smart grid might be able to operate for much of the time independently and turn only to the larger system where it cannot meet its own needs. The problem with reduced or sporadic electricity infrastructure use is that such assets and infrastructure were built with the expectation that they would be in constant, high volume use and their pricing models are based on that type of use. Where those infrastructure and assets are used less frequently, investors (whether the ratepayer or private) will not see the returns on those investments that they had expected.
The EDA has explored methods of compensating for stranded assets in The Power to Connect (at p. 37). It advocates a fixed charge to cover the costs of the larger infrastructure, as the Ontario Energy Board has already done for residential customers, or a use fee for self-generation. The EDA encourages exploring other business models and ways of earning revenue to ensure that parties are encouraged to adapt to the changing grid.
Balancing the Larger Grid – Finally, another significant challenge is that the IESO and the localized smart grids must work together to keep the broader Province-wide electricity system stable in face of the less predictable needs of the smart grids.
With its benefits and challenges, smart grids will be part of the future of the Ontario energy landscape. We will monitor developments in this space.10-Apr-18
At its basic level, “Distributed Energy Resources” or “DERs” mean generators and controllable loads connected to a local utility’s distribution system or connected behind-the meter to a load.
The generators can use any technology: solar, wind, battery storage, an electric vehicle (EV) that functions like a battery when not being driven, and small natural-gas fired generation. DER generators are typically conceived of as smaller in scale, although there is no technical minimum or maximum generator capacity. A household might have 10 kW solar panels attached to its rooftop. An industrial load might have a 1 MW gas-fired generator behind-the-meter generator.
A controllable load means an electricity consumer that can increase or curtail its consumption in response to the needs of the system. For example, participants in the Independent Electricity System Operator’s (IESO) Demand Response Programs will reduce their electricity consumption in times of high demand on the Province’s power grid. These consumers receive compensation for their participation.
Why are Distributed Energy Resources so important? DERs will bring about a once-in-a-generation transformation of the power grid.
Traditionally the power grid was designed to be a Province-wide network supplied by behemoth generators (like Ontario Power Generation’s 3,512 MW Darlington Nuclear Facility or TransCanada’s 683 MW Halton Hills Generating Station). Electricity flows down to the local utilities and from there to the consuming homes and businesses.
DERs open the door to smaller networks of electricity generation and consumption. The consumer - businesses and households -will both generate and consume and become an active participant in the microgrid. When electricity prices are high, the consumer can turn to its generating assets. Add energy storage technology, and the consumer may be able to sell power back to the grid during times of peak pricing. Selecting the most cost- effective electricity supply can be automated or remotely managed, so all of this energy management can occur without the consumer needing to actively monitor it.
How does Ontario get from where we are now to a multitude of DER networks? Every actor in the process from electricity generation to consumption will see their role change.
Businesses, Industry and Households: Conceivably, every business, industrial facility and household could have a generator or battery storage attached to it. Alternatively, a group of loads could pool their resources for a shared DER asset. When electricity prices are high, these consumers would flip on their generator or battery.
Households especially will find their role changing from passive recipient of electricity to active participants in the local network – purchasing and selling power, connecting and disconnecting from the network depending on need, and exchanging electricity use data and intentions with other participants.
Generators and Storage: There is a near-future need for small scale generation at a cost accessible to households and businesses and that does not require expertise to implement and operate.
The Minister of Energy recently issued a directive to the IESO to create a program to explore innovative renewable DER projects.
Local Distribution Companies: LDCs will also see their role change. Potentially, the may become the centre of their DER network – creating the enabling platform and managing the network.
Legal and Regulatory Changes: The Province will need to implement a number of legal and regulatory changes to allow DER networks to form and operate. Cybersecurity, privacy and the protection of information will also be a critical requirement to their secure functioning.
The Province has already given some indications as to the types and size of DER assets that will be eligible for Provincial support. For example, in Ontario's 2017 Long Term Energy Plan, behind-the-meter combined heat and power projects that use fossil fuels to generate electricity will no longer be eligible for incentives under the Conservation First or Industrial Accelerator program. The IESO’s Process & Systems Initiative limits incentives to behind-the-meter generation with a nameplate capacity of 20 MW or less.
Grid Stability: Traditionally, the power grid was designed around the concept that the larger the scale, the greater the stability. Electricity system operators across jurisdictions in North America work together to smooth the peaks and valleys of power consumption to stabilize the power grid.
DERs represent a new challenge to system operators as they will need to work with DER networks and incorporate them into existing electricity markets.
As this transformation occurs in Ontario over the next fifteen to twenty years, there will be lots of opportunity for all generators and consumers of electricity – in other words, for everybody.
February 9, 2018
This post is a simplified version of a checklist I use with my clients who are considering going into business together. For the purposes of this post, I use the term “partners” both in the sense of partners in a legal partnership under the Partnerships Act (Ontario) and the joint owners of a private company.
It is often helpful to have a full and frank discussion about each partner’s role and expectations before entering into the business relationship. With roles and expectations clearly articulated and agreed to, the partners can then focus on running the business and avoid potential issues down the road. With that in mind, I am listing below the five most important points that business partners should discuss with each other and of which they should have a clear picture.
1. Contributions to the Business: The business may need additional capital contributions in the future. The partners should agree on how that need will be met. Contributions can also mean the time, work effort, physical or intellectual property, and role in growing the business that each partner is expected to deliver. Partners may also wish to consider how a business would address an extended absence by a partner (either a voluntary or involuntary absence).
2. Management and Control of the Business: Business partners are encouraged to consider the major decisions that will face the business and whether those decisions will require the agreement of all partners. These types of decisions might include borrowing money or a transaction over a specified monetary threshold, entering into a new line of business or accepting a new partner. Shareholders may want a guarantee that they will hold a director or officer position to ensure that they have direct control and oversight over the day-to-day operations of the business. It is also worth noting that in taking a director or officer position, the shareholder attracts additional liability that s/he would not otherwise have.
3. Compensation: A key feature of a partnership and shareholder agreement is to address the amount of compensation each business partner will receive, when it will be paid out and any conditions that need to be satisfied to receive it.
4. Exiting the Business: Shareholder and partnership agreements typically address how a partner(s) might exit the business. Because partners in privately held companies and partnerships typically work closely together, most businesses will only permit an exiting partner to sell his/her shares or units to a third party if the remaining partners have consented. The purpose is to give the remaining partners control over the people with whom they go into business. For example, the remaining partners might have the right to repurchase the exiting partner’s shares.
Corporate law has developed a variety of tools that can be incorporated into a shareholder agreement to make an exit fair to all parties. For example, a minority shareholder might want “piggy back” rights to ensure that he/she receives the same price and terms as a majority shareholder on the sale of the Business.
It is also advisable to develop a plan for the business or the other partners to repurchase the shares or units if a partner ceases to be active in the business. Of particular importance is developing a method for assigning a value to the business at the time of exit. “Fair market value” is the concept that is typically used, which can be assessed by a third party business valuation service.
I would note that any remedy that involves the business or the remaining partners purchasing shares or units is only useful if the purchaser has access to the funds necessary to buy out the exiting partner. Parties are encouraged to consider their relative access to funds when designing the exit provisions.
5. Resolving Disputes: Business partners are also encouraged to consider mechanisms for resolving disputes. A starting mechanism might be to require the partners to negotiate for a period in good faith to reach a solution. If the parties cannot resolve the issue, the parties might go to mediation. Failing that, the parties might then have the option to trigger a winding up.
The “shot gun” clause, also called a “buy-sell agreement”, is a well publicized (if risky) mechanism for triggering an exit. One partner may deliver both an offer to purchase the other partner’s shares and an offer to sell his/her shares on identical terms. The receiving partner makes the decision to purchase the business or to sell out his/her interest.
The obligations set out in shareholder and partnership agreements are legally binding and enforceable. A partner who does not fulfill his/her obligations under it can be ordered by a court to perform the agreement or be found liable to the other partners for damages.
Shareholder and partnership agreements are useful tools to help businesses run smoothly and reduce conflict. Parties going into business together are encouraged to explore and discuss how they see their relationship working, and then crafting a structure tailored to their needs.
February 2, 2018
On October 26, 2017, the Ministry of Energy released its third Long Term Energy Plan (LTEP). The 2017 LTEP, titled Delivering Fairness and Choice, summarizes the Province's successes in implementing a clean energy system that is 90% free of climate-change causing green house gas emissions, and sets out the energy policy direction for the Province over the next 20 years.
As with previous energy policies, this LTEP indicates a number of potential opportunities for businesses to reduce their energy costs, as well as areas of potential high future growth with Provincial support. Below I discuss what I see as the top five areas where small and medium sized business may be able to benefit from energy programs and contracts:
1. Demand Response, Demand Management, Load Shifting or Load Curtailment: These terms all refer to a business reducing its energy consumption during times of high demand on the Province’s electricity grid, such as when air conditioners are running at full blast on the hottest summer days or lights and heaters are running on the coldest winter days. Conceptually, the business would shift its production to another time when the Provincial electricity demand is lower, like evenings or weekends. The Province benefits by not needing to build additional generation capacity. The business benefits by being paid to shift its electricity consumption to other times.
There are already a number of programs in place where businesses receive payment to reduce their electricity consumption during periods of high demand.
The Independent Electricity System Operator (IESO) holds an annual auction in early December, where businesses can bid in the MW quantity of electricity (capacity) by which they can reduce their electricity consumption. The clearing price for the period between May 1, 2017 and April 30, 2018 ranged between $275 to $331 /MW. Bidders in this capacity auction are typically aggregators, or businesses that "aggregate" and manage the capacities of other businesses to provide demand response in exchange for payment.
The Industrial Conservation Initiative (ICI) is another demand response program offered by the IESO through which businesses can reduce their global adjustment costs by reducing their electricity consumption during the top five periods of peak Provincial electricity consumption in a year. On average, participation in ICI can reduce a business' electricity bills by 1/3.
ICI was initially open only to large industrials, but beginning in the summer of 2017, eligibility was expanded to include all customers with an average monthly peak demand of more than 1 MW, and manufacturers in certain targeted sectors and greenhouses with an average monthly peak demand greater than 500 kW. Manufacturers can participate by opting in by June 15 of each year. For businesses that are not eligible for ICI, the Ontario Energy Board (OEB) is reviewing the way that the global adjustment is charged to them, and may introduce a comparable program.
Demand response features heavily in the 2017 LTEP as well as in forecasts for market renewal. Businesses can expect increased opportunities to provide demand response capacity. This should also mean increased opportunities for advisers and experts to assist businesses in taking advantage of these programs.
2. Distributed Energy Resources: A Distributed Energy Resource (DER) is a decentralized source of energy. The 2017 LTEP contemplates a network of thousands (or perhaps millions) of DERs providing energy to individual homes or communities.
Current examples of DERS are:
When not supplying energy to its immediate consumer, the DER could sell the energy or the demand response capacity back to the grid.
As the price of these technologies drops, they become increasingly accessible to individuals and businesses and the potential for a stable network of DERs grows.
The 2017 LTEP indicates that we can expect a call for DER demonstration projects involving innovative renewable generation. With respect to net metering of small-scale generation, the 2017 LTEP also contemplates some novel ownership arrangements that may present exciting opportunities for consumers as well as companies interested in investing in or building renewable energy facilities.
3. Electric Cars: The Province forecasts 2.4 million electric vehicles on the road in Ontario by 2035. The Province, the OEB and local utility companies will explore technologies to integrate electric cars into the current electric system, such as in-home charging stations, or programs in which the owner of an electric car receives payments for charging their car at times when there is less demand on the grid. The Province is also exploring electrification of transit, school buses and rail.
4. Energy Storage: Energy storage is the ability to store energy on a large scale for long periods, like a battery. It is generally understood to be a game changing technology in that energy could be stored during periods of low demand for use during periods of high demand. It would dramatically change traditional estimates of the need for energy generating facilities. The Province has engaged in several pilots and studies of energy storage since 2016. We can certainly expect more on this front in the future.
5. Near and Net Zero Emission Buildings: Near and net zero emission buildings are homes and buildings that produce no carbon emissions or nearly none. The 2017 LTEP highlights the following technologies to get a building to zero emissions:
Conservation programs promoting these technologies will be complemented by amendments to the Ontario Building Code similarly aimed at reducing GHG emissions.
Overall, the 2017 LTEP indicates that how we consume electricity will undergo some radical changes in the next few years. Businesses and investors that want to be a part of that can anticipate a large number of conservation and demand side management opportunities in the coming years.
Long Term Energy Plan 2017: files.ontario.ca/books/ltep2017_0.pdf
December 7, 2017
Of the $1.9 Billion in yearly revenues expected from Cap and Trade in Ontario, the Province has committed $25 Million to assist small and medium-sized businesses in implementing technical and process upgrades and improvements that will reduce the consumption of green house gases (GHG).
The funding is available through the SMART Green Program delivered by Canadian Manufacturers & Exporters (CME) in three streams: (1) up to $2,500 for a high level, walk-through assessment to identify potential upgrades or improvements; (2) up to $15,000 for a detailed assessment, or $30,000 where gas metering is required; and (3) reimbursement of 50% of certain eligible costs up to $500,000 for actually implementing the upgrade/improvement project.
Businesses may apply for a grant by submitting an application to CME. Grants are available until all funding has been awarded. All projects must be implemented by December 31, 2018 and all post-implementation deliverables must be completed by March 31, 2019.
In this article, I review the terms and conditions of the contribution agreement (Contribution Agreement) for receiving funding under stream (3), project implementation, (which can be found here: cmeweb.crm.eperformanceinc.com/smartgreen/PROJECT_FUNDING_Contribution_
In particular, I highlight opportunities and risks that may be of particular interest to owners of small and medium-sized business.
Funding under stream (3) is payable in three installments. The first 30% is payable within 30 days after entering into the Contribution Agreement. The second installment of 50% is payable within 30 days after the project is completed. The balance is payable approximately two to five months later after the business submits a post-completion report describing the project.
Businesses should be aware that they are responsible for carrying the majority of the costs of implementing the project. For example, assume a project costing $1 Million made up of eligible costs. Under the SMART Green Program, a business could potentially be eligible to receive up to $500,000 to offset the costs. Upon signing, the business would receive the first $150,000. The business would be responsible for funding the remaining $850,000 of the project until its completion. Only then would it receive reimbursement of the balance of $350,000 in two payments over the next few months.
Applicants should also be aware that CME retains discretion to determine which costs are eligible for reimbursement. Project costs that are determined not to be reasonable could be refused. A business may be required to prove to CME (or potentially an arbitrator or judge) that a cost is reasonable. An applicant may wish to seek advice if it is concerned a particular cost may not be covered.
Related to the requirement that all costs be reasonable, the business cannot use the funds in a manner in which there is an actual or perceived conflict of interest. For example, it cannot sub-contract part of the project to an engineering company that is owned by a director (unless it puts that contract out for tender and follows additional prescribed steps).
An unusual feature of this type of contract is that it is sprinkled with clauses in which CME/the Province reserve the right to "escape" their obligations. For example, CME has the right to terminate the Contribution Agreement without cause (see Section 5.4), and CME's obligation to provide funding is contingent on CME receiving funds from the Province (see Section 2.3.4).
These escape hatches for CME/the Province put businesses in a precarious position. One of the eligibility requirements is that the business demonstrate a financial need for the SMART Program grant, and that without it, the project would have failed to meet a desired performance indicator. Potentially, the business could find itself in a position where it undertook a project with the expectation of being reimbursed 50% of its costs, only to have its counter party exercise its right not to provide funding. Businesses will need to assess their comfort with these payment provisions.
Pre-Project and Construction Restrictions
The full list of SMART Green's eligibility requirements is available on CME's website (link: cmeweb.crm.eperformanceinc.com/smartgreen/), including number of employees and GHG emission levels. Some notable eligibility requirements include the following:
1. Participants in Ontario's Cap and Trade Program are not eligible (However, CME has indicated a willingness to accept projects that receive support from other programs. Businesses should seek advice to ensure they are obtaining all available support for their green projects.)
2. Only projects for which a business has not yet begun to incur costs are eligible for SMART Green funding. Businesses that may be considering efficiency upgrades should explore the SMART Green Program prior to committing to any costs of a project.
3. Once the business submits its grant application, it cannot make any changes to the project without CME's express approval. If it fails to obtain approval, it may risk losing its funding.
Post-Completion Project Restrictions
Businesses should also be aware that they are required to own their project for a minimum of six years. For that same six-year period, if more than 51% of a business' equity ownership changes hands, CME can require the business to return the funding. Potential applicants should assess this contractual obligation in light of their longer-term plans.
Publicity and Information Disclosure
The Province will almost certainly wish to share the success stories arising from SMART Green projects. A successful project may result not only in the reduction of GHG emissions, but the creation of jobs, improved productivity, and other benefits to the economy. Accordingly, the Contribution Agreement contains provisions that may require participating businesses to publicize the project. For example, the business may be required to participate in a media event with the Ministry of Economic Development and Growth, or publicly share details on the business and project as directed.
While green publicity is typically a benefit to the business as well, businesses must also be careful to ensure that any confidential or sensitive information about the business' operations or processes are not inadvertently disclosed. Where a business has a particular concern about such information becoming publicly available, it should seek advice as to the likelihood of that risk.
As the steward of public funds, CME is also required to ensure that the funding is spent responsibly and in accordance with the terms of the Contribution Agreement. As such the Contribution Agreement grants CME a broad right to require the business to make available to it "any information" requested by CME (See section 4.8).
SMART Green presents a unique opportunity for businesses to obtain public support for initiatives that benefit both business and the environment, but (as with any commercial agreement) applicants should have a clear understanding of their rights and obligations from the outset. If you have any questions about this article or the provisions of the Contribution Agreement, please feel free to contact me at email@example.com.
For a link to the SMART Green program, please see: cmeweb.crm.eperformanceinc.com/smartgreen/
September 29, 2017
Here are the top three most common pitfalls I have seen in contract management.
1. Missing deadlines. Contracts typically contain a multitude of key dates: dates when you or the other party is required to deliver something, the deadline for giving the other party notice about something or the date that the contract ends. Missing these deadlines can be critical.
In many cases, contracts will renew automatically unless one party gives the other notice that they want out of the contract by a specific deadline. The deadline for notice is often 90, 60 or 30 days prior to the end date of the contract.Â If you miss that date, you may be liable for paying for another year of services.
Lawyers call it a tickler system, with the idea, I suppose, that the system tickles you when you have a deadline. I always recommend that immediately after signing a contract, my clients enter the keys dates into their calendars. The dates should be in a company-wide calendar - not just the contract manager's personal calendar, in case the contract manager is on holiday, or sick or leaves the company. The system should also alert you with enough time to act on the deadline.
2. Accidentally amending the contract. It can be surprisingly easy to amend a contract without realizing it. If you or an employee agrees to vary the terms of a contract by e-mail or over the phone, this is an amendment to the contract.
Even if the change is minor, such as agreeing that a delivery can be extended by a few days or making a minor change to the product, the contract has still been amended and the original term is no longer enforceable. Sometimes even a yup, or a nod, even silence or a failure to reply to an e-mail has been misunderstood by a counterparty as your agreeing to the amendment. If you had not intended to agree to the amendment, or had agreed to it too quickly without thinking through the full ramifications or if an employee agreed to the amendment without authority, it can lead to problems later on.
For the above reason exactly, many contracts will contain a clause that says the contract can only be amended if the amendment is in writing. While it is important to include this clause, the "amendments in writing only" clause does not mean that you will never be held to the accidental amendment.
There are a variety of ways to manage this risk, and businesses should explore which are best for them.
3. Accidentally waiving your rights. Along the same lines as accidentally amending a contract, it can be surprisingly easy to waive your rights under a contract.
A waiver happens when you let the other side know that you will not be exercising one of your rights under a contract. Once you have waived that right, it is for good. You cannot at a later time try to resurrect it. For example, if you tell a supplier that it is okay if the product they supply does not include a specific feature, you are precluded from later on requiring the product to have that feature.
Waivers should always be clear and clearly limited to the specific instance.
September 5, 2017
Canada's Anti-Spam Law or CASL states that you can send an e-mail, text or other electronic message advertizing your product, only if (a) the person you are sending it to has consented to receive it; and (b) the message clearly tells the recipient who is sending it and allows the recipient to unsubscribe from your e-mail list.
The potential fines for getting CASL wrong can be a business-ending event ($1 million for an individual and $10 million for a corporation, and the legislation contemplates that unhappy recipients will have, at some point in the future, a right to sue for damages as well.). It pays to make sure you are in compliance with CASL before hitting send.
This post focuses on complying with part (a) above. Compliance with CASL is a primarily a record keeping exercise. For every e-mail address in the "to" field, you should be able to show that the recipient expressly or implicitly consented to receive the e-mail. One way to help you manage your e-mail addresses is to create a database (or if you don't have an IT person to develop a database, and Excel spreadsheet will do). The database should record, at a minimum, each person's name, e-mail address, the type of consent, the date of the consent , whether the consent relates only to a specific kind of content, and evidence of the consent. For example, where the consent is express consent in the form of an e-mail from the recipient signing up for your newsletter, the evidence will be that e-mail.
A recipient only provides implied consent in certain circumstances. Implied consent is also time-limited, which means that you will need to regularly update your database to remove any consents that have expired.
The most common circumstances where a recipient is understood to give you implied consent are where the recipient has purchased your product or service within the last two years, or the recipient has inquired about your product or service within the last six months. Another frequently used category of implied consent for e-mail addresses found on-line is that the e-mail is relevant to the recipient's business function. (To use this category, the recipient cannot have not stated that they do not wish to receive e-mails). For example, a bakery wishes to sell desserts. It could send an e-mail to the purchasing manager of a grocery store, but could not send it to the IT person. The bakery also could not send an e-mail to a dentist office.
Where the recipient asks to be unsubscribed from your list, you must remove them within 10 days.
If you are ever faced with a CASL related complaint, one of the strongest defenses is to be able to show that the complainant consented either expressly or implicitly to receive the e-mails. You should also be able to show that you have CASL policies and processes together with a careful record keeping system in place to show that you are in compliance with CASL. It is just as important to make sure that employees, staff and marketing or advertizing services who send e-mails on your behalf of or on behalf of your corporation are aware of and understand the policies and fully comply with them.
August 14, 2017
*Not legal advice. Information contained on this website is intended as general information only. In some cases, I have simplified the description of the law in order to provide you with the "big picture". In addition, the above posts may not be updated to reflect changes in the law after posting. Please do not rely on the information above without consulting a lawyer.
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