Manitoba Hydro's burgeoning debt surpasses $19 billion


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Manitoba Hydro Debt Load surges past $19.2B as the Crown corporation faces shrinking net income, restructuring costs, and PUB rate decisions, driven by Bipole III, Keeyask construction, aging infrastructure, and rising interest rate risks.

 

Key Points

Manitoba Hydro Debt Load refers to the utility's escalating borrowings exceeding $19B, pressuring rates and finances.

✅ Debt rose to $19.2B; projected near $25B within five years.

✅ Major drivers: Bipole III, Keeyask, aging assets, restructuring.

✅ Rate hikes sought; PUB approved 3.6% vs 7.9% request.

 

Manitoba Hydro's debt load now exceeds $19 billion as the provincial Crown corporation grapples with a shrinking net income amid ongoing efforts to slay costs.

The utility's annual report, to be released publicly on Tuesday, also shows its total consolidated net income slumped from $71 million in 2016-2017 to $37 million in the last fiscal year, mirroring a Hydro One profit drop as electricity revenue fell.

It said efforts to restructure the utility and reduce costs are partly to blame for the $34 million drop in year-over-year income.

These earnings come nowhere close, however, to alleviating Hydro's long-term debt problem, a dynamic also seen in a BC Hydro deferred costs report about customer exposure. The figure is pegged at $19.2 billion this fiscal year, up from $16.1 billion the previous year and $14.2 billion in 2016.

The utility projects its debt will grow to about $25 billion in the next five years. Its largest expenses include finishing the Bipole III line, working on the Keeyask Generating System that is halfway done and rebuilding aging wood poles and substations, the report said.

"This level of debt increases the potential financial exposure from risks facing the corporation and is a concern for both

the corporation and our customers who may be exposed to higher rate increases in the event of rising interest rates, a prolonged drought or a major system failure," outgoing president and CEO Kelvin Shepherd wrote.

The income drop is primarily a result of the $50 million spent in the form of restructuring charges associated with the utility's efforts to streamline the organization and drive down costs, amid NDP criticism of Hydro changes related to government policy.

Those efforts included the implementation of buyouts for employees through what the utility dubbed its "voluntary departure program."

Among the changes, Manitoba Hydro reduced its workforce by 800 employees, which is expected to save the utility over $90 million per year. It also reduced its management positions by 26 per cent, a Monday news release said, while Hydro One leadership upheaval in Ontario drove its shares down during comparable governance turmoil.

To improve its financial situation, Hydro has applied for rate increases, even as the Consumers Coalition pushes to have the proposal rejected. The Public Utilities Board offered a 3.6 per cent average rate hike, instead of the 7.9 per cent jump the utility asked for.

In May, when the PUB rendered its decision, it made several recommendations as an alternative to raising rates, including receiving a share of carbon tax revenue and asking the government to help pay for Bipole III.

Hydro is projecting a net income of $70 million for 2018-2019, which includes the impact of the recent rate increase. That total reflects an approximately 20 per cent reduction in net income from 2017-18 after restructuring costs are calculated.

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Florida says no to $400M in federal solar energy incentives

Florida Solar for All Opt-Out highlights Gov. DeSantis rejecting EPA grant funds under the Inflation Reduction Act, limiting low-income households' access to solar panels, clean energy programs, and promised electricity savings across disadvantaged communities.

 

Key Points

Florida Solar for All Opt-Out is the state declining EPA grants, restricting low-income access to solar energy savings.

✅ EPA grant under IRA aimed at low-income solar

✅ Estimated 20% electricity bill savings missed

✅ Florida lacks PPAs and renewable standards

 

Florida has passed up on up to $400 million in federal money that would have helped low-income households install solar panels.

A $7 billion grant “competition” to promote clean energy in disadvantaged communities by providing low-income households with access to affordable solar energy was introduced by President Joe Biden earlier this year, and despite his climate law's mixed results in practice, none of that money will reach Florida households.

The Environmental Protection Agency announced the competition in June as part of Biden’s Inflation Reduction Act. However, Florida Gov. Ron DeSantis has decided to pass on the $400 million up for grabs by choosing to opt out of the opportunity.

Inflation Reduction Act:What is the Inflation Reduction Act? Everything to know about one of Biden's big laws

The program would have helped Florida households reduce their electricity costs by a minimum of 20% during a key time when Floridians are leaving in droves due to a rising cost of living associated with soaring insurance costs, inflation, and proposed FPL rate hikes statewide.

Florida was one of six other states that chose not to apply for the money.

President Joe Biden announced a $7 billion “competition” to promote clean energy in disadvantaged communities.

The opportunity, named “Solar for All,” was announced by the EPA in June and promised to provide up to $7 billion in grants to states, territories, tribal governments, municipalities, and nonprofits to expand the number of low-income and disadvantaged communities primed for residential solar investment — enabling millions of low-income households to access affordable, resilient and clean solar energy.

The grant is intended to help lower energy costs for families, create jobs and help reduce greenhouse effects that accelerate global climate change by providing financial support and incentives to communities that were previously locked out of investments.


How much money would Floridians save under the ‘Solar for All’ solar panel grant?

The program aims to reduce household electricity costs by at least 20%. Florida households paid an average of $154.51 per month for electricity in 2022, just over 14% of the national average of $135.25, and debates over hurricane rate surcharges continue to shape customer bills, according to the U.S. Energy Information Administration. A 20% savings would drop those bills down to around $123 per month.

On the campaign trail, DeSantis has pledged to unravel Biden’s green energy agenda if elected president, amid escalating solar policy battles nationwide, slamming the Inflation Reduction Act and what he called “a concerted effort to ramp up the fear when it comes to things like global warming and climate change.”

His energy agenda includes ending Biden’s subsidies for electric cars while pushing policies that he says would ramp up domestic oil production.

“The subsidies are going to drive inflation higher,” DeSantis said at an event in September. “It’s not going to help with interest rates, and it is certainly not going to help with our unsustainable debt levels.”

DeSantis heading to third debate:As he enters third debate, Ron DeSantis has a big Nikki Haley problem

DeSantis’ plan to curb clean energy usage in Florida seems to be at odds with the state as a whole, and the region's evolving strategy for the South underscores why it has been ranked among the top three states to go solar since 2019, according to the Solar Energy Industries Association (SEIA).

SEIA also shows, however, that Florida lags behind many other states when it comes to solar policies, as utilities tilt the solar market in ways that influence policy outcomes statewide. Florida, for instance, has no renewable energy standards, which are used to increase the use of renewable energy sources for electricity by requiring or encouraging suppliers to provide customers with a stated minimum share of electricity from eligible renewable resources, according to the EIA.

Power purchase agreements, which can help lower the cost of going solar through third-party financing, are also not allowed in Florida, with court rulings on monopolies reinforcing the existing market structure. And there have been other policies implemented that drove other potential solar investments to other states.

 

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DBRS Confirms Ontario Power Generation Inc. at A (low)/R-1 (low), Stable Trends

OPG Credit Rating affirmed by DBRS at A (low) issuer and unsecured debt, R-1 (low) CP, Stable trends, backed by a supportive regulatory regime, strong leverage metrics, and provincial support; monitor Darlington Refurbishment costs.

 

Key Points

It is DBRS's confirmation of OPG at A (low) issuer and unsecured, R-1 (low) CP, with Stable outlooks.

✅ Stable trends; strong cash flow-to-debt and capital ratios

✅ Provincial financing via OEFC; Fair Hydro Trust ring-fenced

✅ Darlington Refurbishment on budget; cost overruns remain risk

 

DBRS Limited (DBRS) confirmed the Issuer Rating and the Unsecured Debt rating of Ontario Power Generation Inc. (OPG or the Company) at A (low) and the Commercial Paper (CP) rating at R-1 (low), amid sector developments such as Hydro One leadership efforts to repair government relations and measures like staff lockdowns at critical sites.

All trends are Stable. The ratings of OPG continue to be supported by (1) the reasonable regulatory regime in place for the Company's regulated generation facilities, including stable pricing signals for large users, (2) strong cash flow-to-debt and debt-to-capital ratios and (3) continuing financial support from its shareholder, the Province of Ontario (the Province; rated AA (low) with a Stable trend by DBRS). The Province, through its agent, the Ontario Electricity Financial Corporation (rated AA (low) with a Stable trend by DBRS), provides most of OPG's financing (approximately 43% of consolidated debt). The Company's remaining debt includes project financing (31%), including projects such as a battery energy storage system proposed near Woodstock, non-recourse debt issued by Fair Hydro Trust (Senior Notes rated AAA (sf), Under Review with Negative Implications by DBRS; 11%), CP (2%) and Senior Notes issued under the Medium Term Note Program (12%).

In March 2019, the Province introduced 'Bill 87, Fixing the Hydro Mess Act, 2019' which includes winding down the Fair Hydro Plan, and later introduced electricity relief to mitigate customer bills during the COVID-19 pandemic. OPG will remain as the Financial Services Manager for the outstanding Fair Hydro Trust debt, which will become obligations of the Province. DBRS does not expect this development to have a material impact on the Company as (1) the Fair Hydro Trust debt will continue to be bankruptcy-remote and ring-fenced from OPG (all debt is non-recourse to the Company) and (2) the credit rating on the Company's investment in the Subordinated Notes (rated AA (sf), Under Review with Negative Implications by DBRS) will likely remain investment grade while the Junior Subordinated Notes (rated A (sf), Under Review with Developing Implications by DBRS) will not necessarily be negatively affected by this change (see the DBRS press release, 'DBRS Maintains Fair Hydro Trust, Series 2018-1 and Series 2018-2 Notes Under Review,' dated March 26, 2019, for more details).

OPG's key credit metrics improved in 2018, following the approval of its 2017-2021 rates application by the Ontario Energy Board in December 2017, alongside the Province's energy-efficiency programs that shape demand. The Company's profitability strengthened significantly, with corporate return on equity (ROE) of 7.8% (adjusted for a $205 million gain on sale of property; 5.1% in 2017) closer to the regulatory allowed ROE of 8.78%. However, DBRS continues to view a positive rating action as unlikely in the short term because of the ongoing large capital expenditures program, including the $12.8 billion Darlington Refurbishment project, amid ongoing oversight following the nuclear alert investigation in Ontario. However, a downgrade could occur should there be significant cost overruns with the Darlington Refurbishment project that result in stranded costs. DBRS notes that the Darlington Refurbishment project is currently on budget and on schedule.

 

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US January power generation jumps 9.3% on year: EIA

US January power generation climbed to 373.2 TWh, EIA data shows, with coal edging natural gas, record wind output, record nuclear generation, rising hydro, and stable utility-scale solar amid higher Henry Hub prices.

 

Key Points

US January power generation hit 373.2 TWh; coal led gas, wind and nuclear set records, with solar edging higher.

✅ Coal 31.8% share; gas 29.4%; coal output 118.7 TWh, gas 109.6 TWh.

✅ Wind hit record 26.8 TWh; nuclear record 74.6 TWh.

✅ Total generation 373.2 TWh, highest January since 2014.

 

The US generated 373.2 TWh of power in January, up 7.9% from 345.9 TWh in December and 9.3% higher than the same month in 2017, Energy Information Administration data shows.

The monthly total was the highest amount in January since 377.3 TWh was generated in January 2014.

Coal generation totaled 118.7 TWh in January, up 11.4% from 106.58 TWh in December and up 2.8% from the year-ago month, consistent with projections of a coal-fired generation increase for the first time since 2014. It was also the highest amount generated in January since 132.4 TWh in 2015.

For the second straight month, more power was generated from coal than natural gas, as 109.6 TWh came from gas, up 3.3% from 106.14 TWh in December and up 19.9% on the year.

However, the 118.7 TWh generated from coal was down 9.6% from the five-year average for the month, due to the higher usage of gas and renewables and a rising share of non-fossil generation in the overall mix.

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Coal made up 31.8% of the total US power generation in January, up from 30.8% in December but down from 33.8% in January 2017.

Gas` generation share was at 29.4% in the latest month, with momentum from record gas-fired electricity earlier in the period, down from 30.7% in December but up from 26.8% in the year-ago month.

In January, the NYMEX Henry Hub gas futures price averaged $3.16/MMBtu, up 13.9% from $2.78/MMBtu averaged in December but down 4% from $3.29/MMBtu averaged in the year-ago month.

 

WIND, NUCLEAR GENERATION AT RECORD HIGHS

Wind generation was at a record-high 26.8 TWh in January, up 29.3% from 22.8 TWh in December and the highest amount on record, according to EIA data going back to January 2001. Wind generated 7.2% of the nation`s power in January, as an EIA summer outlook anticipates larger wind and solar contributions, up from 6.6% in December and 6.1% in the year-ago month.

Utility-scale solar generated 3.3 TWh in January, up 1.3% from 3.1 TWh in December and up 51.6% on the year. In January, utility-scale solar generation made up 0.9% of US power generation, during a period when solar and wind supplied 10% of US electricity in early 2018, flat from December but up from 0.6% in January 2017.

Nuclear generation was also at a record-high 74.6 TWh in January, up 1.3% month on month and the highest monthly total since the EIA started tracking it in January 2001, eclipsing the previous record of 74.3 TWh set in July 2008. Nuclear generation made up 20% of the US power in January, down from 21.3% in December and 21.4% in the year-ago month.

Hydro power totaled 25.4 TWh in January, making up 6.8% of US power generation during the month, up from 6.5% in December but down from 8.2% in January 2017.

 

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High Natural Gas Prices Make This The Time To Build Back Better - With Clean Electricity

Build Back Better Act Energy Savings curb volatile fossil fuel heating bills by accelerating electrification and renewable electricity, insulating households from natural gas, propane, and oil price spikes while cutting emissions and lowering energy costs.

 

Key Points

BBBA policies expand clean power and electrification to curb volatility, lower bills, and cut emissions.

✅ Tax credits for renewables, EVs, and efficient all-electric homes

✅ Shields households from natural gas, propane, and heating oil spikes

✅ Cuts methane, lowers bills, and improves grid reliability and jobs

 

Experts are forecasting serious sticker shock from home heating bills this winter. Nearly 60 percent of United States’ households heat their homes with fossil fuels, including natural gas, propane, or heating oil, and these consumers are expected to spend much more this winter because of fuel price increases.

That could greatly burden many families and businesses already operating on thin margins. Yet homes that use electricity for heating and cooking are largely insulated from the pain of volatile fuel markets, and they’re facing dramatically lower price increases as a result.

Projections say cost increases for households could range anywhere from 22% to 94% more, depending on the fuel used for heating and the severity of the winter temperatures. But the added expenditures for the 41% of U.S. households using electricity for heating are much less stark—these consumers will see only a 6% price increase on average. The projected fossil fuel price spikes are largely due to increased demand, limited supply, declining fuel stores, and shifting investment priorities in the face of climate change.

The fossil fuel industry is already seizing this moment to use high prices to persuade policymakers to vote against clean energy policies, particularly the Build Back Better Act (BBBA). Spokespeople with ties to the fossil fuel industry and some consumer groups are trying to pin higher fuel prices on the proposed legislation even before it has passed, even as analyses show the energy crisis is not spurring a green revolution on its own, let alone begun impacting fuel markets. But the claim the BBBA would cost Americans and the economy is false.

The facts tell a different story. Adopting smart climate policies and accelerating the clean energy transition are precisely the solutions to counter this vicious cycle by ending our dependance on volatile fossil fuels. The BBBA will ensure reliable, affordable clean electricity for millions of Americans, in line with a clean electricity standard many experts advocate—a key strategy for avoiding future vulnerability. Unlike fossil fuels subject to the whims of a global marketplace, wind and sunshine are always free. So renewable-generated electricity comes with an ultra-low fixed price decades into the future.

By expanding clean energy and electric vehicle tax credits, creating new incentives for efficient all-electric homes, and dedicating new funding for state and local programs, the BBBA provides practical solutions that build on lessons from Biden's climate law to protect Americans from price shocks, save consumers money, and reduce emissions fueling dangerous climate change.


What’s really causing the gas price spikes?
The U.S. Energy Information Administration’s winter 2021 energy price forecasts project that homes heated with natural gas, fuel oil, and propane will see average price increases of 30%, 43%, and 54%, respectively. Those who heat their homes with electricity, on the other hand, should expect a modest 6% increase. At the pump, drivers are seeing some of the highest gas prices in nearly a decade as the U.S. energy crisis ripples through electricity, gas, and EV markets today. And the U.S. is not alone. Countries around the globe are experiencing similar price jumps, including Britain's high winter energy costs this season.

A closer look confirms the cause of these high prices is not clean energy or climate policies—it’s fossil fuels themselves.  

First, the U.S. (and the world) are just now feeling the effects of the oil and gas industry’s reduced fuel production and spending due to the pandemic. COVID-19 brought the world’s economies to a screeching halt, and most countries have not returned to pre-COVID economic activity. During the past 20 months, the oil and gas industry curtailed its production to avoid oversupply as demand fell to all-time lows. Just as businesses were reopening, stored fuel was needed to meet high demand for cooling during 2021’s hottest summer on record, driving sky-high summer energy bills for many households. February’s Texas Big Freeze also disrupted gas distribution and production.

The world is moving again and demand for goods and services is rebounding to pre-pandemic levels. But even with higher energy demand, OPEC announced it would not inject more oil into the economy. Major oil companies have also held oil and gas spending flat in 2021, with their share of overall upstream spending at 25%, compared with nearly 40% in the mid-2010s. And as climate change threats loom in the financial world, investors are reducing their exposure to the risks of stranded assets, increasingly diversifying and divesting from fossil fuels. 

Second, despite strong and sustained growth for renewable energy, energy storage, and electric vehicles, the relatively slow pace to adopt fossil fuel alternatives at scale has left U.S. households and businesses tethered to an industry well-known for price volatility. Today, some oil drillers are using profits from higher gas prices to pay back debt and reward shareholders as demanded by investors, instead of increasing supply. Rising prices for a limited commodity in high demand is generating huge profits for many of the world’s largest companies at the expense of U.S. households.

Because 48% of homes use fossil gas for heating and another 10% heat with propane and fuel oil, more than half of U.S. households will feel the impact of rising prices on their home energy bills. One in four U.S. households continues to experience a high energy burden (meaning their energy expenses consume an inordinate amount of their income), including risks of pandemic power shut-offs that deepen energy insecurity, and many are still experiencing financial hardships exacerbated by the pandemic. Those with inefficient fossil-fueled appliances, homes, and cars will be hardest hit, and many families with fixed- and lower-incomes could be forced to choose between heat or other necessities.

We have the solutions—the BBBA will unlock their benefits for all households

Short-term band-aids may be enticing, but long-term policies are the only way out of this negative feedback loop. Clean energy and building electrification will prevent more costly disasters in the future, but they’re the very solutions the fossil fuel industry fights at every turn. All-electric homes and vehicles are a natural hedge against the price spikes we’re experiencing today since renewables are inherently devoid of fuel-related price fluctuations.

RMI analysis shows all-electric single-family homes in all regions of the country have lower energy bills than a comparable mixed fuel-homes (i.e., electricity and gas). Electric vehicles also save consumers money. Research from University of California, Berkeley and Energy Innovation found consumers could save a total of $2.7 trillion in 2050—or $1,000 per year, per household for the next 30 years—if we accelerate electric vehicle deployment in the coming decade.

The BBBA would help deliver these consumer savings by expanding and expediting clean energy, while ensuring equitable adoption among lower-income households and underserved communities. Extending and expanding clean energy tax credits; new incentives for electric vehicles (including used electric vehicles); and new incentives for energy efficient homes and all-electric appliances (and electrical upgrades) will reduce up-front costs and spur widespread adoption of all-electric homes, buildings, and cars.

A combination of grants, incentives, and programs will promote private sector investments in a decarbonized economy, while also funding and supporting state and local governments already leading the way. The BBBA also allocates dedicated funding and makes important modifications (such as higher rebate amounts and greater point-of-purchase availability) to ensure these technologies are available to low-income households, underserved urban and rural communities, tribes, frontline communities, and people living in multifamily housing.

Finally, the BBBA proposes to make oil and gas polluters pay for the harm they are causing to people’s health and the climate through a methane fee. This fee would cost companies less than 1% of their revenue, meaning the industry would retain over 99% of its profits. In return return we’d see substantial reductions of a powerful greenhouse gas and a healthier environment in communities living near fossil fuel production. These benefits also come with a stronger economy—Energy Innovation analysis shows the methane fee would create more than 70,000 jobs by 2050 and boost gross domestic product more than $250 billion from 2023 to 2050.

The facts speak for themselves. Gas prices are rising because of reasons totally unrelated to smart climate and clean energy policies, which research shows actually lower costs. For the first time in more than a decade, America has the opportunity to enact a comprehensive energy policy that will yield measurable savings to consumers and free us from oil and gas industry control over our wallets.

The BBBA will help the U.S. get off the fossil fuel rollercoaster and achieve a stable energy future, ensuring that today’s price spikes will be a thing of the past. Proving, once and for all, that the solution to our fossil fuel woes is not more fossil fuels.

 

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Consumers Coalition wants Manitoba Hydro?s proposed rate increase rejected

Manitoba Hydro Interim Rate Increase faces PUB scrutiny as consumers coalition challenges a 5% electricity rate hike, citing drought planning, retained earnings, affordability, transparency, and impacts on fixed incomes and northern communities.

 

Key Points

A proposed 5% electricity rate hike under PUB review, opposed by consumers citing drought planning and affordability.

✅ Coalition backs 2% hike; 5% seen as undue burden

✅ PUB review sought; interim process lacks transparency

✅ Retained earnings, efficiencies cited to offset drought

 

The Consumers Coalition is urging the Public Utilities Board (PUB) to reject Manitoba Hydro’s current interim rate increase application, amid ongoing debates about Hydro governance and policy.

Hydro is requesting a five per cent jump in electricity rates starting on January 1, claiming drought conditions warrant the increase but the coalition disagrees, saying a two per cent increase would be sufficient.

The coalition, which includes Harvest Manitoba, the Consumers’ Association of Canada-Manitoba, and the Aboriginal Council of Winnipeg, said a 5 per cent rate increase would put an unnecessary strain on consumer budgets, especially for those on fixed incomes or living up north.

"We feel that, in many ways, Manitobans have already paid for this drought," said Gloria Desorcy, executive director of the Consumers’ Association of Canada - Manitoba.

The coalition argues that hydroelectric companies already plan for droughts and that hydro should be using past earnings to mitigate any losses.

The group claims drought conditions would have added about 0.8 per cent to Hydro’s bottom line. They said remaining revenues from a two per cent increase could then be used to offset the increased costs of major projects like the Keeyask generating station and service its growing debt obligations.

The group also said Hydro is financially secure and is projecting a positive net income of $112 million next year without rate increases, even as utility profits can swing with market conditions, assuming the drought doesn’t continue.

They argue Hydro can use retained earnings as a tool to mitigate losses, rather than relying on deferral accounting that shifts costs, and find further efficiencies within the corporation.

"So we said two per cent, which is much more palatable for consumers especially at the time when so many consumers are struggling with so many higher bills,” said Desorcy.

According to the coalition’s calculations, that works out to a $2-4 increase per month, and debates such as ending off-peak pricing in Ontario show how design affects bills, depending on whether electricity is used for heating, but it could be higher.

The coalition said their proposed two per cent rate increase should be applied to all Manitoba Hydro customers and have a set expiration date of January 1, 2023.

Another issue, according to the coalition, is the process of an interim rate application does not provide any meaningful transparency and accountability, whereas recent OEB decisions in Ontario have outlined more robust public processes.

Desorcy said the next step is up to the PUB, though board upheaval at Hydro One in Ontario shows how governance shifts can influence outcomes.

The board is expected to decide on the proposed increase in the next couple of weeks.

 

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Are Net-Zero Energy Buildings Really Coming Soon to Mass?

Massachusetts Energy Code Updates align DOER regulations with BBRS standards, advancing Stretch Code and Specialized Code beyond the Base Energy Code to accelerate net-zero construction, electrification, and high-efficiency building performance across municipal opt-in communities.

 

Key Points

They are DOER-led changes to Base, Stretch, and Specialized Codes to drive net-zero, electrified, efficient buildings.

✅ Updates apply Base, Stretch, or opt-in Specialized Code.

✅ Targets net-zero by 2050 with electrification-first design.

✅ Municipalities choose code path via City Council or Town Meeting.

 

Massachusetts will soon see significant updates to the energy codes that govern the construction and alteration of buildings throughout the Commonwealth.

As required by the 2021 climate bill, the Massachusetts Department of Energy Resources (DOER) has recently finalized regulations updating the current Stretch Energy Code, previously promulgated by the state's Board of Building Regulations and Standards (BBRS), and establishing a new Specialized Code geared toward achieving net-zero building energy performance.

The final code has been submitted to the Joint Committee on Telecommunications, Utilities, and Energy for review as required under state law, amid ongoing Connecticut market overhaul discussions that could influence regional dynamics.

Under the new regulations, each municipality must apply one of the following:

Base Energy Code - The current Base Energy Code is being updated by the BBRS as part of its routine updates to the full set of building codes. This base code is the default if a municipality has not opted in to an alternative energy code.

Stretch Code - The updated Stretch Code creates stricter guidelines on energy-efficiency for almost all new constructions and alterations in municipalities that have adopted the previous Stretch Code, paralleling 100% carbon-free target in Minnesota and elsewhere to support building decarbonization. The updated Stretch Code will automatically become the applicable code in any municipality that previously opted-in to the Stretch Code.

Specialized Code - The newly created Specialized Code includes additional requirements above and beyond the Stretch Code, designed to get to ensure that new construction is consistent with a net-zero economy by 2050, similar to Canada's clean electricity regulations that set a 2050 decarbonization pathway. Municipalities must opt-in to adopt the Specialized Code by vote of City Council or Town Meeting.

The new codes are much too detailed to summarize in a blog post. You can read more here. Without going into those details here, it is worth noting a few significant policy implications of the new regulations:

With roughly 90% of Massachusetts municipalities having already adopted the prior version of the Stretch Code, the Commonwealth will effectively soon have a new base code that, even if it does not mandate zero-energy buildings, is nonetheless very aggressive in pushing new construction to be as energy-efficient as possible, as jurisdictions such as Ontario clean electricity regulations continue to reshape the power mix.

Although some concerns have been raised about the cost of compliance, particularly in a period of high inflation, and amid solar demand charge debates in Massachusetts, our understanding is that many developers have indicated that they can work with the new regulations without significant adverse impacts.

Of course, the success of the new codes depends on the success of the Commonwealth's efforts to transition quickly to a zero-carbon electrical grid, supported by initiatives like the state's energy storage solicitation to bolster reliability. If the cost of doing so is higher than expected, there could well be public resistance. If new transmission doesn't get built out sufficiently quickly or other problems occur, such that the power is not available to electrify all new construction, that would be a much more significant problem - for many reasons!

In short, the new regulations unquestionably set the Commonwealth on a course to electrify new construction and squeeze carbon emissions out of new buildings. However, as with the rest of our climate goals, there are a lot of moving pieces, including proposals for a clean electricity standard shaping the power sector that are going to have to come together to make the zero-carbon economy a reality.

 

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