The four-page report says: “Ontario is our nation’s leader in clean wind energy with an installed capacity of 5,076 MW, about 40 per cent of Canada’s total installed wind energy capacity. There are 2,577 wind turbines currently operating in Ontario at 96 separate facilities.” It goes on to say “Supplying 7.7 per cent of Ontario’s electricity demand today, wind energy helps to diversify Ontario’s electricity generation mix.”
What CanWEA’s report doesn’t say is that wind represents over 12% of grid-connected generation and that the 7.7% supply it adds to the grid is intermittent, unreliable and frequently (65% of the time it is actually generating power) out of sync with demand. As an example, on Friday September 14, 2018 at hour 18 (6 PM), when demand in Ontario was near or at its peak, the 4,400 MW of grid-connected wind generated a miserly 10 MWh.
That’s 0.23% of capacity.
To put the 10 MWh in context, that is enough to supply one average household with electricity for a year. At the same time as wind was probably consuming more electricity than the turbines were generating, gas plants (installed to back up wind capacity) were generating 3,862 MWh.
Total generation for hour 18 was 19,274 MWh, not including net imports (imports less exports) of 1,249 MWh, representing Ontario grid demand of 20,523 MWh.* That means the 12% of grid-connected wind generation contributed 0.05% of grid demand. For the full 24 hours of the 14th of September, wind generated just over 3,500 MWh which equates to 3.3% of their capacity. If that isn’t bad enough, 2,500 MWh of that generation occurred from 12 AM to 7 AM when demand is lowest. Needless to say, nuclear, hydro and gas supplied the bulk of Ontario demand for the day.
What this all means is that industrial wind capacity does nothing more than add to the costs of the generation of electricity in Ontario, and, actually, pretty well everywhere else in the world.
Ontario can’t and shouldn’t fall for the hyperbolic self-interested wind spin, so hopefully our politicians recognize it for what it does—drive up the cost of electricity while killing birds and bats and inflicting harm to humans in rural communities due to the audible and inaudible noise emitted.
*IESO’s Daily Market Summary indicates Ontario’s peak demand was 20,845 MWh on September 14, 2018.
A warm summer meant electricity use went up and costs went down. Is there a lesson here?
With Ontario experiencing a relatively warm summer, I thought it might be interesting to look at three recent months, starting with May 2018, to see if power consumption had increased compared to the same period in 2017.
As it turned out, May, June and July in 2018 versus the same three months in 2017 resulted in an increase in total demand (Ontario consumption plus net exports [exports less imports]) of 1,447,000 MWh or 3.9%. With “net exports” dropping by 1,120,000 MWh, Ontario consumption actually increased by 2,567,000 or 7%. This increase occurred despite the continued spending of approximately $400 million annually on conservation initiatives.
You might expect that an increase in power consumption by that much in Ontario would have resulted in a substantial increase in the cost of electricity, but as it happens, the amount was a meager $73 million for that extra 2,567,000 MWh. Based on the average cost (GA + HOEP) of electricity over those three months, the additional cost should have been around $313 million. The additional consumption cost only 2.8 cents per kWh (kilowatt hour).
The question is: why did that additional consumption (enough to power 1.1 million average households for the three months) cost so little?
There are several reasons why! First, curtailed wind (paid for but not added to the grid) in 2018 was 416,400 MWh* less than 2017. That means the savings from lower curtailment was approximately $50 million.
As well, Ontario’s net exports were thus lower by 1,120,000 MWh — that saved Ontario ratepayers the full cost of the GA (the GA averaged about $101/MWh in 2018) or approximately $113 million.
And, the 3.4 million MWh of net exports in 2017 generated only about $8/MWh versus $20/MWh in 2017 (the approximate GA for the three months in 2017 versus 2018) for the 2,280,000 MWh of net exports in 2018 for a net benefit in 2018 of about $18 million.
If one totes up the additional costs of $73 million plus the wind curtailed savings of $50 million, the $113 million saved due to reduced net exports, and the $18 million extra earned on export sales due to a higher GA in 2018, it comes to $254 million or $59 million short of the $313 million noted above.
I suspect the unexplained $59 million is related to: spilled hydro, steamed-off nuclear, and a reduction in the Class B to Class A subsidy resulting from the higher average GA. Most of those latter details are not yet publicly available.
Interestingly, wind power — generated and curtailed — was equal to 80% of net exports in 2017 and 112% of net exports in 2018. That suggests wind power was surplus to demand in both years.
It time to acknowledge again that wind, as an intermittent and unreliable source of power, tends to present itself when not needed. That, along with the multiple millions spent by the previous government encouraging electricity consumers to conserve has a simple effect!
Together, they simply drive up the cost of electricity. Perhaps we should increase consumption to drive costs down.
Who gained the most under the Fair Hydro Plan? Not you. Hydro One comes out the winner
In the section titled ”Other Regulatory Developments” in the “Management’s Discussion and Analysis” chapter of Hydro One’s financials for the year ended December 31, 2017, is this interesting note. (The emphasis is mine.)
“In March 2017, Ontario’s Minister of Energy announced the Fair Hydro Plan, which included changes to the Global Adjustment, the Rural or Remote Electricity Rate Protection (RRRP) Program, the introduction of the First Nations rate assistance program, and improving the allocation of delivery charges across the rural and urban geographies of the province. Hydro One worked collaboratively with the OEB on the First Nations rate assistance program, and was a key stakeholder in providing solutions that address both the Global Adjustment and RRRP elements. The Fair Hydro Plan came into effect on July 1, 2017 and resulted in a reduction of approximately 25% on electricity bills for typical Ontario residential customers. The Province also launched a new Affordability Fund aimed at assisting electricity customers who cannot qualify for low-income conservation programs. Additional enhancements were also made to the existing Ontario Electricity Support Program (OESP).
Hydro One customers saw the full benefits of the Fair Hydro Plan for all electricity consumed after July 1, 2017. A typical rural residential customer using 750 kWh per month will see savings on their monthly bills of 31% on average, or approximately $600 annually. These changes did not have an impact on the net income of the Company.”
Now, fast-forward to the release of Hydro One’s 2018 2nd Quarter results and there is no mention of the Fair Hydro Plan, the Global Adjustment, the RRRP or the First Nations rate assistance program!
In the recent report, Hydro One simply brags about the big jump in its net income. That jump was supposedly due to approval of a substantial transmission rate increase and favourable weather noted as “higher energy consumption resulting from colder weather in April 2018”!*
The actual growth in revenue for the six months was only $24 million; however, after-tax net income** year over year increased from $284 million to $422 million, showing an increase of $138 million or 48.6% for the comparable six months.
Dreams come true … for Hydro One
If one looks at gross revenue less the cost of “purchased power,” Hydro One’s RoR (Return on Revenue) for the six months was 25.6% (after-tax). Any other service provider or retailer could only dream about growth like that!
So, was the $138 million improvement in net profit a reflection on the now retired, six-million-dollar man’s achievements or other factors?
Let’s look at a few aspects of the results.
As it turns out, the “substantial transmission rate increase” generated additional revenue of $123 million. The transmission revenue is paid for by all local distribution companies (LDC) and included in the “delivery” line on electricity bills. The result of the $123-million increase collected by Hydro One (and all LDC) in delivery costs should have increased that line on the bills, but for Hydro One customers, it didn’t! The “delivery” costs for Hydro One customers is estimated to have decreased from about 8.2 cents/kWh to 5.4 cents/kWh and “distribution” revenue fell by $96 million despite increased demand of 5.4% (697,000 MWh) in the comparable six months.
Another significant item affecting the positive results is related to what Hydro One paid for the cost of power which fell (despite increased demand) by $113 million from $1.538 billion to $1.425 billion and also fell for “delivery” line items previously included on hydro bills.
The kickbacks, under the Fair Hydro Plan, resulted from moving the “purchased power” costs to future ratepayers and by moving costs of issues such as the OESP*** and “conservation” spending to current taxpayers.
Those cost shifts naturally had a positive effect on Hydro One’s earnings.
In addition, and as noted in an article in the Ottawa Citizen Hydro One is responsible for monitoring “the energy production and pay thousands of FIT and MicroFit producers across the province, it is no longer able to share any information about those contracts publicly.”
Worthy of our trust?
Hydro is simply required to submit a bill to the IESO for the generation produced for all the MicroFIT contracted parties on their distribution network. Those bills are submitted monthly without scrutiny by the OEB or IESO, and IESO simply writes them a cheque the cost of which is billed to all of Ontario’s ratepayers.
Should we trust Hydro One’s billing process for those thousands of FIT and MicroFIT producers, knowing that back in 2015 Ontario’s Ombudsman reported they issued more than 100,000 faulty bills to their customers? Privatization by the former Ontario Liberal government has resulted in a monopoly, now operating without oversight.
The Ottawa Citizen article about this issue had a fitting comment from Steve Aplin, an energy environment data specialist (website Emmissiontrak): “That’s what happens when you break up this system. Now, nobody is minding the store. It’s outrageous that the IESO, they send the cheques. You don’t just blindly send a cheque off to somebody. There must be some fiduciary responsibility.”
The results of Hydro One working “collaboratively” with the OEB reduced revenue in a positive way for them, as they shifted costs to future ratepayers and current taxpayers, generating higher profits.
Additionally, despite ratepayers picking up the billions in costs for “smart meters” and the “smart grid” neither the OEB or the IESO seem able to execute their fiduciary responsibility!
From all appearances, improving results for shareholders is more important now than containing costs for ratepayers and taxpayers for Hydro One, IESO and the OEB.
It’s not over: Ontario taxpayers and ratepayers will be paying for the past government’s mismanagement for years to come. Here’s how… and how much.
The last in a series on the IESO
August 2, 2018
The two earlier articles about Ontario Independent Electricity System Operator or IESO revealed the fact that it could be “gamed” — and in fact, it was! To the tune of $100 million, by just one generator.
Needless to say, any gaming by a local distribution company (LDC) also may be happening. Why would I suggest that? When I asked the IESO why the Fair Hydro Plan “Variance” amount was so high for May 2018, they said this:
“Please note that settlement data submitted to the IESO by the LDCs is not audited by the IESO (audit responsibilities reside with the OEB) and is processed as submitted.”
The May “Variance” amount was $309.9 million. More disturbing is that the first six months of the current year has rung up $1.180 billion in the “Variance” which could represent $2.360 billion for 2018 if the last six months are similar.
The results to date of the FHP “Variance” amount is well in excess of the calculations presented by the Ontario Financial Accountability Office (FAO) in their review, which had the following note:
“Figure 3-3 summarizes the FAO’s estimate of the annual cost of the FHP through to 2045-46. The FAO estimates the cost of the FHP to the Province will peak at $1.8 billion in 2020-21, after which the FAO assumes that the electricity relief programs will no longer be funded by the Province. The HST rebate is forecast to cost $0.9 billion in 2021-22, rising rapidly to $1.6 billion by 2028-29”.
The average suggested by the FAO per year was $1.750 billion, so, at the current rate of accrual, future Ontario ratepayers may be looking at total of almost $9.5 billion (without including interest costs) added to our electricity bills.
Taxpayers will be affected too: They’ll have to bear the costs of lost revenue of about $4.1 billion (plus interest costs) associated with the HST rebate and another $3 billion associated with “Adjusting Electricity Relief Programs”. The latter includes the RRRP (Regulated and Remote Rate Program) the OESP (Ontario Electricity Support Program) and a new First Nations On-Reserve Delivery Credit and Affordability Fund.
So, the 17-percent reduction on our electricity bills, coupled with the HST foregone tax revenue plus the cost of those “Relief Programs” represents $16.6 billion of spending, without interest costs.
What are we getting for $16B?
What are we getting for that $16.6 billion? No new power generation. No new transmission lines or upgrades to LDC infrastructure. Simply more wasted money, lots of it, as a result of the Green Energy Act.
Questions put to the IESO about the May Variance amount got the following response from them:
“Hi Parker– the increase in GA deferral in May is mainly due to most LDCs submitting settlement data to the IESO based on the second GA estimate which was unusually high (i.e., 13.2 cent/KWh) in May. LDCs submit May settlement data to IESO during the first four business days of June at which time the actual GA rate would not have been calculated yet as per IESO’s settlement schedule. Each month there is a true up when LDCs submit their data to the IESO for the previous month plus an estimate of the current month they are submitting for.”
Read that and you have to ask, Why? Why not settle the Variance account once IESO has determined “the actual GA rate” rather than go through a series of wasted financial maneuvers? Logic doesn’t seem to be a formula used or followed within the electricity sector.
Are the ratepayers and taxpayers being “gamed” or can we trust IESO with our hard-earned money and believe that each and every action by them is truly being “audited” by the OEB?
I will leave the foregoing question to be answered by an “Electricity Audit” that will hopefully be conducted by Ontario’s new government.
John Manley of the Business Council of Canada is complaining that cancelling wind power contracts is bad for business. But he says high electricity costs are bad for business, too.
July 27, 2018
The unwanted and unneeded 18.45 MW White Pines wind power project being erected in Prince Edward County is receiving a lot of attention. The people in “The County” have been fighting the project for years with some success and were continuing that fight. Nevertheless, IESO granted wpd Canada an NTP (notice to proceed) after the writ for the Ontario election was drawn up, and the power developer charged ahead.
They did so knowing the newly elected Premier Ford-led government were proceeding with a “special act” in the Ontario Legislature to stop the project. German owned wpd ignored the backdating of the “act” to July 10, 2018 and in response to the “act” (noted in a CBC article) responded: “The company has indicated that it will seek to recoup $100-million that it has sunk into the project, but it is not clear how much the provincial government will agree to pay. The legislation requires wpd to cover the cost of decommissioning the project and to restore the land to ‘clean and safe condition’.”
The action caused Berlin’s ambassador to Canada Sabine Sparwasser to suggest the move to cancel the project represents a black mark for the province in the eyes of foreign investors: “Obviously, every incoming government has the right to change policy direction. But to have a unilateral cancellation pushed through by law that way is unsettling for the company, but is also something that will unsettle other potential investors.”
Shortly after, John Manley, President of the Business Council of Canada, wrote a letter to Premier Ford in which he said: “(The Act) would revoke permits several years after the proponent obtained them from the appropriate regulatory bodies, cancel contracts with the Independent Electricity System Operator that were negotiated in good faith and unilaterally set the terms upon which the proponent may be eligible for compensation.” What Mr. Manley failed to note is that wpd were facing three charges under the Environmental Protection Act and the NTP was issued after the writ period, so it was in fact the proponent who failed to act in “good faith”. Mr. Manley did not fully investigate the circumstances surrounding the proposed act and simply sided with the developer without consideration of the other contentious issues.
Interesting is a letter Mr. Manley sent to Premier Wynne, last June 15, 2017 in which he noted: “According to the Ministry of Finance’s Long-Term Report on the Economy, Ontario’s average annual growth rate is projected to slow to 2.2 per cent between 2016-2020. At the same time, businesses in Ontario are adjusting to sharply higher electricity rates, higher CPP contribution rates and the implementation of a cap-and-trade program for greenhouse gas reductions.”
Yet another letter Mr. Manley sent to Glen Murray, then Ontario’s Minster of the Environment and Climate Change back in March 2015 stated: “Ontario firms are facing a number of challenges, not the least of which is higher electricity costs as a result of policies already adopted by the government.”
It would appear Mr. Manley, a former Liberal MP and Deputy Prime Minister of Canada, failed to realize how industrial wind turbines helped cause those “higher electricity costs.” At the same time, he seems to condone the actions of parties who fail to follow legislation meant to protect voters and our environment.
Mr. Manley and the Council he represents cannot have it both ways.
The wind power lobbyist makes impressive claims but reality is a different story
In a bid to be assertive after the Speech from the Throne last Thursday and Premier Ford’s pronouncement of the upcoming demise of the Green Energy Act, CanWEA’s (Canadian Wind Energy Association) President Robert Hornung issued the following announcement
He made some impressive claims.
“Maintaining investor confidence in the Ontario marketplace is important for Ontario’s short- and long-term economic prosperity. The Canadian Wind Energy Association (CanWEA) shares the Ontario Government’s commitment to an affordable and reliable electricity system that benefits Ontarians. CanWEA notes that wind energy projects in Ontario are an important source of sustained revenue for municipal and Indigenous partners. Ontario’s wind energy projects are providing long-term, stable pricing for Ontario ratepayers. Wind energy is now the lowest-cost option for new electricity supply in Ontario, across Canada, and throughout much of the world.”
Focusing on the weekend immediately following Mr. Hornung’s announcement is an interesting exercise. Examining his use of the words “reliable electricity system” is worthwhile to see if it has any bearing on generation from industrial wind turbines (IWT).
As it turns out, both Saturday July 14th and Sunday July 15th delivered pretty average summer days with Ontario demand of 837,000 MWh and total demand (including net exports) of 910,000 MWh. Over those two days, grid-connected IWTs in Ontario delivered 11,329 MWh.
What that means: wind turbines operated at a capacity value that was 5.4% of their rated capacity of over 4,400 MW. Peak output was at 12 AM on July 14th when they generated 969 MWh or 22% of rated capacity. The lowest output was at 10 AM on July 15th when they were probably consuming more than their output of 26 MWh, or 0.6% of their rated capacity.
Wind power generators represent 11.9% of total grid-connected capacity in Ontario according to IESO, so if they are promoted as part of “reliable” electricity, it’s not too far a reach to expect them to demonstrate their reliability.
It appears CanWEA’s claim is false.
Over the two weekend days they generated 1.4% of Ontario’s demand and only 1.2% of total demand.
If that is considered a “reliable” electricity source, Ontario’s ratepayers have been taking it on the chin since the wind contracts were awarded. Those contracts have had the opposite effect of bringing Ontario “short- and long-term economic prosperity” as our electricity cost increases have been more than double those of our neighbours.
All Ontario’s ratepayers are grateful that nuclear and hydro generation, (supported by gas generators during peak periods) were up and running over the past weekend.
Now all we ratepayers need is for the President of CanWEA to finally confess: wind power is intermittent and NOT reliable, and, oh yes, very expensive!
Many will recall Bob Chiarelli, when in the position as Ontario’s Minister of Energy, was questioned on the costs of exporting our surplus electricity on TVO and stated: “since 2008, the province of Ontario – and you can verify it with the IESO – has made a $6 billion profit on the trading of electricity.”
Needless to say Minister Chiarelli was called out by the media and opposition parties for making such a spurious claim.
Let’s look at Ontario’s 2017 electricity exports and see what he would claim about them. The U.S. Energy Administration Information (EIA) in a recent release, had the following information posted from data supplied by Canada’s National Energy Board (NEB):
“Electricity accounts for a small, but locally important, share of bilateral trade. In 2017, the value of U.S. imports of electricity from Canada increased for the second straight year, reaching $2.3 billion*. The United States imported 72 million megawatt hours of electricity from Canada in 2017 and exported 9.9 million megawatt hours, based on data from Canada’s National Energy Board.”
As it turns out, Ontario’s exports of 19.1 million megawatt hours (MWh) in 2017 represents 26.5% of the 72 million MWh reported as exported by the NEB and those 19.1 million MWh generated “revenue” of $496.6 million (approximately) made up of the $15.80/MWh of the yearly average HOEP (hourly Ontario energy price) as reported by IESO and another $10.20/MWh for transmission** costs.
The implied revenue generated represented 16.6%* of total Canadian electricity revenue versus 26.5% of total Canadian electricity exports. The Ontario based generators of that 19.1 TWh of power were paid a yearly average of $115.5 million/TWh (yearly average includes HOEP plus global adjustment based on the IESO’s December 2017 monthly summary.
That means the cost to Ontario ratepayers for exported power was $1,709.5 billion and the credit (net of the monies to Hydro One of $194.8 million for transmission) resulted in Ontario’s ratepayers picking up the missing revenue of $1,507.7. Anyone with a small math knowledge would not refer to that as a profit as it would represent a cost of about $300 per Ontario household.
The cost to ratepayers of electricity exports in 2017 at over $1.5 billion and prior years played a significant role in driving up electricity rates and represented almost 10% of total generation costs. To put that in current context, Ontario’s ratepayers were slapped with an “export tariff” by our Ontario government of 88% which greatly exceeds the US tariffs recently announced by the US government on Canadian manufactured steel and aluminum.
Getting slapped with only a 10% or 25% tariff would be a net benefit to Ontario’s ratepayers.
*Presumably US dollars so would represent approximately $3 billion CDN dollars at a $1.30/$1.00 exchange rate.
**A large part of these revenues ($194.8 million estimated) went to Hydro One who control about 99% of all transmission in the province.