Manitoba Hydro hikes face opposition as hearings begin


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Manitoba Hydro rate hikes face public hearings over electricity rates, utility bills, and debt, with impacts on low-income households, Indigenous communities, and Winnipeg services amid credit rating pressure and rising energy costs.

 

Key Points

Manitoba Hydro seeks 7.9% annual increases to stabilize finances and debt, impacting electricity costs for households.

✅ Proposed hikes: 7.9% yearly through 2023/24

✅ Driven by debt, credit rating declines, rising interest

✅ Disproportionate impact on low-income and Indigenous communities

 

Hearings began Monday into Manitoba Hydro’s request for consecutive annual rate hikes of 7.9 per cent.  The crown corporation is asking for the steep hikes to commence April 1, 2018.

The increases would continue through 2023/2024, under a multi-year rate plan before dropping to what Hydro calls “sustainable” levels.

Patti Ramage, legal counsel for Hydro, said while she understands no one welcomes the “exceptional” rate increases, the company is dealing with exceptional circumstances.

It’s the largest rate increase Hydro has ever asked for, though a scaled-back increase was discussed later, saying rising debt and declining credit ratings are affecting its financial stability.

President and CEO Kelvin Shepherd said Hydro is borrowing money to fund its interest payments, and acknowledged that isn’t an effective business model.

Hydro’s application states that it will be spending up to 63 per cent of its revenue on paying financial expenses if the current request for rate hikes is not approved.

If it does get the increase it wants, that number could shrink to 45 per cent – which Ramage says is still quite high, but preferable to the alternative.

She cited the need to take immediate action to fix Hydro’s finances instead of simply hoping for the best.

“The worst thing we can do is defer action… that’s why we need to get this right,” Ramage said.

A number of intervenors presented varying responses to Hydro’s push for increased rates, with many focusing on how the hikes would affect Manitobans with lower incomes.

Senwung Luk spoke on behalf of the Assembly of Manitoba Chiefs, and said the proposed rates would hit First Nations reserves particularly hard.

He noted that 44.2 per cent of housing on reserves in the province needs significant improvement, which means electricity use tends to be higher to compensate for the lower quality of infrastructure.

Luk says this problem is compounded by the higher rates of poverty in Indigenous populations, with 76 per cent of children on reserves in Manitoba living below the poverty line.

If the increase goes forward, he said the AMC hopes to see a reduced rate for those living on reserves, despite a recent appeal court ruling on such pricing.

Byron Williams, speaking on behalf of the Consumers Coalition, said the 7.9 per cent increase unreasonably favours the interests of Hydro, and is unjustly biased against virtually everyone else.

In Saskatchewan, the NDP criticized an SaskPower 8 per cent rate hike as unfair to customers, highlighting regional concerns.

Williams said customers using electric space heating would be more heavily targeted by the rate increase, facing an extra $13.14 a month as opposed to the $6.88 that would be tacked onto the bills of those not using electric space heating.

Williams also called Hydro’s financial forecasts unreliable, bringing the 7.9 per cent figure into question.

Lawyer George Orle, speaking for the Manitoba Keewatinowi Okimakanak, said the proposed rate hikes would “make a mockery” of the sacrifices made by First Nations across the province, given that so much of Hydro’s infrastructure is on Indigenous land.

The city of Winnipeg also spoke out against the jump, saying property taxes could rise or services could be cut if the hikes go ahead to compensate for increased, unsustainable electricity costs.

In British Columbia, a BC Hydro 3 per cent increase also moved forward, drawing attention to affordability.

A common theme at the hearing was that Hydro’s request was not backed by facts, and that it was heading towards fear-mongering.

Manitoba Hydro’s CEO begged to differ as he plead his case during the first hearing of a process that is expected to take 10 weeks.

 

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PG&E Supports Local Communities as It Pays More Than $230 Million in Property Taxes to 50 California Counties

PG&E property tax payments bolster counties, education, public safety, and infrastructure across Northern and Central California, reflecting semi-annual levies tied to utility assets, capital investments, and economic development that serve 16 million customers.

 

Key Points

PG&E property tax payments are semi-annual county taxes funding public services and linked to utility infrastructure.

✅ $230M paid for Jul-Dec 2017 across 50 California counties

✅ Estimated $461M for FY 2017-2018, up 12% year over year

✅ Investments: $5.9B in grid, Gas Safety Academy, control center

 

Pacific Gas and Electric Company (PG&E) paid property taxes of more than $230 million this fall to the 50 counties where the energy company owns property and operates gas and electric infrastructure that serves 16 million Californians. The tax payments help support essential public services like education and public health and safety actions across the region.

The semi-annual property tax payments made today cover the period from July 1 to December 31, 2017.

Total payments for the full tax year of July 1, 2017 to June 30, 2018 are estimated to total more than $461 million—an increase of $50 million, or 12 percent, compared with the prior fiscal year, even as customer rates are expected to stabilize in the years ahead.

“Property tax payments provide crucial resources to the many communities where we live and work, supporting everything from education to public safety. By continuing to make local investments in gas and electric infrastructure, we are not only creating one of the safest and most reliable energy systems in the country, including wildfire risk reduction programs and related efforts, we’re investing in the local economy and helping our communities thrive,” said Jason Wells, senior vice president and chief financial officer for PG&E.

PG&E invested more than $5.7 billion last year and expects to invest $5.9 billion this year to enhance and upgrade its gas and electrical infrastructure amid power line fire risks across Northern and Central California.

Some recent investments include the construction of PG&E’s $75 millionGas Safety Academy in Winters in Yolo County, which opened in September. Last year, PG&E opened a $36 million, state-of-the-art electric distribution control center in Rocklin.

PG&E supports the communities it serves in a variety of ways. In 2016, PG&E provided more than $28 million in charitable contributions to enrich local educational opportunities, preserve the environment, and support economic vitality and emergency preparedness and safety, including its Wildfire Assistance Program for impacted residents. PG&E employees provide thousands of hours of volunteer service in their local communities. The company also offers a broad spectrum of economic development services to help local businesses grow.

 

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EVs could drive 38% rise in US electricity demand, DOE lab finds

EV-Driven Electricity Demand Growth will reshape utilities through electrification, EV adoption, grid modernization, and ratebasing of charging, as NREL forecasts rising terawatt-hours, CAGR increases, and demand-side flexibility to manage emissions and reliability.

 

Key Points

Growth in power consumption fueled by EV adoption and electrification, increasing utility sales and grid investment.

✅ NREL projects 20%-38% higher U.S. load by 2050

✅ Utilities see CAGR up to 1.6% and 80 TWh/year growth

✅ Demand-side flexibility and EV charging optimize grids

 

Utilities have struggled with flat demand for years, but analysis by the National Renewable Energy Laboratory predicts steady growth across the next three decades — largely driven by the adoption of electric vehicles, including models like the Tesla Model 3 that are reshaping expectations.

The study considers three scenarios, a reference case and medium- and high-adoption electrification predictions. All indicate demand growth, but in the medium and high scenarios for 2050, U.S. electricity consumption increases by 20% and 38%, respectively, compared to business as usual.

Utilities could go from stagnant demand to compound annual growth rates of 1.6%, which would amount to sustained absolute growth of 80 terawatt-hours per year.

"This unprecedented absolute growth in annual electricity consumption can significantly alter supply-side infrastructure development requirements," the report says, and could challenge state power grids in multiple regions.

NREL's Trieu Mai, principal investigator for the study, cautions that more research is needed to fully assess the drivers and impacts of electrification, "as well as the role and value of demand-side flexibility."

"Although we extensively and qualitatively discuss the potential drivers and barriers behind electric technology adoption in the report, much more work is needed to quantitatively understand these factors," Mai said in a statement.

However, utilities have largely bought into the dream.

"Electric vehicles are the biggest opportunity we see right now," Energy Impact Partners CEO Hans Kobler told Utility Dive. And the impact could go beyond just higher kilowattt-hour sales, particularly as electric truck fleets come online.

"When the transportation sector is fully electrified, it will result in around $6 trillion in investment," Kobler said. "Half of that is on the infrastructure side of the utility." And the industry can also benefit through ratebasing charging stations and managing the new demand.

One benefit that NREL's report points to is the possibility of "expanded value streams enabled by electric and/or grid-connected technologies," such as energy storage and mobile chargers that enhance flexibility.

"Many electric utilities are carefully watching the trend toward electrification, as it has the potential to increase sales and revenues that have stagnated or fallen over the past decade," the report said, highlighting potential benefits for all customers as adoption grows. "Beyond power system planning, other motivations to study electrification include its potential to impact energy security, emissions, and innovation in electrical end-use technologies and overall efficient system integration. The impacts of electrification could be far-reaching and have benefits and costs to various stakeholders."

 

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New York Achieves Solar Energy Goals Ahead of Schedule

New York Solar Milestone accelerates renewable energy adoption, meeting targets early with 8,000 MW capacity powering 1.1 million homes, boosting green jobs, community solar, battery storage, and grid reliability under the CLCPA clean energy framework.

 

Key Points

It is New York achieving its solar goal early, powering 1.1M homes and advancing CLCPA renewable targets.

✅ 8,000 MW installed, enough to power about 1.1M homes

✅ CLCPA targets: 70 percent renewables by 2030

✅ Community solar, storage, and green jobs scaling statewide

 

In a remarkable display of commitment to renewable energy, New York has achieved its solar energy targets a year ahead of schedule, marking a significant milestone in the state's clean energy journey, and aligning with a national trend where renewables reached a record 28% in April nationwide. With the addition of solar power capacity capable of powering over a million homes, New York is not just setting the pace for solar adoption but is also establishing itself as a leader in the fight against climate change.

A Commitment to Renewable Energy

New York’s ambitious clean energy agenda is part of a broader effort to reduce greenhouse gas emissions and transition to sustainable energy sources. The state's goal, established under the Climate Leadership and Community Protection Act (CLCPA), aims for 70% of its electricity to come from renewable sources by 2030. With the recent advancements in solar energy, including contracts for 23 renewable projects totaling 2.3 GW, New York is well on its way to achieving that goal, demonstrating that aggressive policy frameworks can lead to tangible results.

The Numbers Speak for Themselves

As of now, New York has successfully installed more than 8,000 megawatts (MW) of solar energy capacity, supported by large-scale energy projects underway across New York that are expanding the grid. This achievement translates to enough electricity to power approximately 1.1 million homes, showcasing the state's investment in harnessing the sun’s power. The rapid expansion of solar installations reflects both increasing consumer interest and supportive policies that facilitate growth in the renewable energy sector.

Economic Benefits and Job Creation

The surge in solar energy capacity has not only environmental implications but also significant economic benefits. The solar industry in New York has become a substantial job creator, employing tens of thousands of individuals across various sectors. From manufacturing solar panels to installation and maintenance, the job opportunities associated with this growth are diverse and vital for local economies.

Moreover, as solar installations increase, the state benefits from reduced electricity costs over time. By investing in renewable energy, New York is paving the way for a more resilient and sustainable energy future, while simultaneously providing economic opportunities for its residents.

Community Engagement and Accessibility

New York's solar success is also tied to its efforts to engage communities and increase access to renewable energy. Initiatives such as community solar programs allow residents who may not have the means or space to install solar panels on their homes to benefit from solar energy. These programs provide an inclusive approach, ensuring that low-income households and underserved communities have access to clean energy solutions.

The state has also implemented various incentives to encourage solar adoption, including tax credits, rebates, and financing options. These efforts not only promote environmental sustainability but also aim to make solar energy more accessible to all New Yorkers, furthering the commitment to equity in the energy transition.

Innovations and Future Prospects

New York's solar achievements are complemented by ongoing innovations in technology and energy storage solutions. The integration of battery storage systems is becoming increasingly important, reflecting growth in solar and storage in the coming years, and allowing for the capture and storage of solar energy for use during non-sunny periods. This technology enhances grid reliability and supports the state’s goal of transitioning to a fully sustainable energy system.

Looking ahead, New York aims to continue this momentum. The state is exploring additional strategies to increase renewable energy capacity, including plans to investigate sites for offshore wind across its coastline, and other clean energy technologies. By diversifying its renewable energy portfolio, New York is positioning itself to meet and even exceed future energy demands while reducing its carbon footprint.

A Model for Other States

New York’s success story serves as a model for other states aiming to enhance their renewable energy capabilities, with its approval of the biggest offshore wind farm underscoring that leadership. The combination of strong policy frameworks, community engagement, and technological innovation can inspire similar initiatives nationwide. As more states look to address climate change, New York’s proactive approach can provide valuable insights into effective strategies for solar energy deployment.

New York’s achievement of its solar energy goals a year ahead of schedule is a testament to the state's unwavering commitment to sustainability and renewable energy. With the capacity to power over a million homes, this milestone not only signifies progress in clean energy adoption but also highlights the potential for economic growth and community engagement. As New York continues on its path toward a greener future, and stays on the road to 100% renewables by mid-century, it sets a powerful example for others to follow, proving that ambitious renewable energy goals can indeed become a reality.

 

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Four Major Types of Substation Integration Service Providers Account for More than $1 Billion in Annual Revenues

Substation Automation Services help electric utilities modernize through integration, EPC engineering, protective relaying, communications and security, with CAPEX and OPEX insights and a growing global market for third-party providers worldwide rapidly.

 

Key Points

Engineering, integration, and EPC support modernizing utility substations with protection, control, and secure communications

✅ Third-party engineering, EPC, and OEM services for utilities

✅ Integration of multi-vendor devices and platforms

✅ Focus on relays, communications, security, CAPEX-OPEX

 

The Newton-Evans Research Company has released additional findings from its newly published four volume research series entitled: The World Market for Substation Automation and Integration Programs in Electric Utilities: 2017-2020.

This report series has observed four major types of professional third-party service providers that assist electric utilities with substation modernization. These firms range from (1) smaller local or regional engineering consultancies with substation engineering resources to (2) major global participants in EPC work, to (3) the engineering services units of manufacturers of substation devices and platforms, to (4) substation integration specialist firms that source and integrate devices from multiple manufacturers for utility and industrial clients, and often provide substation automation training to support implementation.

2016 Global Share Estimates for Professional Services Providers of Electric Power Substation Integration and Automation Activities

The North American market report (Volume One) includes survey participation from 65 large and midsize US and Canadian electric utilities while the international market report (Volume Two) includes survey participation from 32 unique utilities in 20 countries around the world. In addition to the baseline survey questions, the report includes 2017 substation survey findings on four additional specific topics: communications issues; protective relaying trends; security topics and the CAPEX/OPEX outlook for substation modernization.

Volume Three is the detailed market synopsis and global outlook for substation automation and integration:

Section One of the report provides top-level views of substation modernization, automation & integration and the emerging digital grid landscape, and a narrative market synopsis.

Section Two provides mid-year 2017 estimates of population, electric power generation capacity, transmission substations, including the 2 GW UK substation commissioning as a benchmark, and primary MV distribution substations for more than 120 countries in eight world regions. Information on substation related expenditures and spending for protection and control for each major world region and several major countries is also provided.

Section Three provides information on NGO funding resources for substation modernization among developing nations.

Section Four of this report volume includes North American market share estimates for 2016 shipments of many substation automation-related devices and equipment, such as trends in the digital relay market for utilities.

The Supplier Profiles report (Volume Four) provides descriptive information on the substation modernization offerings of more than 90 product and services companies, covering leading players in the transformer market as well.

 

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Illinois electric utility publishes online map of potential solar capacity

ComEd Hosting Capacity Map helps Illinois communities assess photovoltaic capacity, distributed energy resources, interconnection limits, and grid planning needs, guiding developers and policymakers on siting solar, net metering feasibility, and RPS-aligned deployment by circuit.

 

Key Points

An online tool showing circuit-level DER capacity, PV limits, and interconnection readiness across ComEd.

✅ Circuit-level estimates of solar hosting capacity

✅ Guides siting, interconnection, and net metering

✅ Supports RPS goals with grid planning insights

 

As the Illinois solar market grows from the Future Energy Jobs Act, the largest utility in the state has posted a planning tool to identify potential PV capacity in their service territory. ComEd, a Northern Illinois subsidiary of Exelon, has a hosting capacity website for its communities indicating how much photovoltaic capacity can be sited in given areas, based on the existing electrical infrastructure, as utilities pilot virtual power plant programs that leverage distributed resources.

According to ComEd’s description, “Hosting Capacity is an estimate of the amount of DER [distributed energy resources] that may be accommodated under current configurations at the overall circuit level without significant system upgrades to address adverse impacts to power quality or reliability.” This website will enable developers and local decision makers to estimate how much solar could be installed by township, sections and fractions of sections as small as ½ mile by ½ mile and to gauge EV charging impacts with NREL's projection tool for distribution planning. The map sections indicate potential capacity by AC kilowatts with a link to to ComEd’s recently upgraded Interconnection and Net Metering homepage.

The Hosting Map can provide insight into how much solar can be installed in which locations in order to help solar reach a significant portion of the Illinois Renewable Portfolio Standard (RPS) of 25% electricity from renewable sources by 2025, and to plan for transportation electrification as EV charging infrastructure scales across utility territories. For example, the 18 sections of Oak Park Township capacity range from 612 to 909 kW, and total 13,260 kW of photovoltaic power. That could potentially generate around 20 million kWh, and policy actions such as the CPUC-approved PG&E EV program illustrate how electrification initiatives may influence future demand. Oak Park, according to the PlanItGreen Report Card, a joint project of the Oak Park River Forest Community Foundation and Seven Generations Ahead, uses about 325 million kWh.

Based on ComEd’s Hosting Capacity, Oak Park could generate about 6% of its electricity from solar power located within its borders. Going significantly beyond this amount would likely require a combination of upgrades by ComEd’s infrastructure, potentially higher interconnection costs and deployment of technologies like energy storage solutions. What this does indicate is that a densely populated community like Oak Park would most likely have to get the majority of its solar and renewable electricity from outside its boundaries to reach the statewide RPS goal of 25%. The Hosting Capacity Map shows a considerable disparity among communities in ½ mile by ½ mile sections with some able to host only 100-200 kWs to some with capacities of over 3,000 kW.

 

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California just made more clean energy than it needed

CAISO Net Negative Emissions signal moments when greenhouse gas intensity of serving ISO demand drops below zero, driven by high renewable generation, low load, strong solar exports, and imports accounting in the California grid.

 

Key Points

Moments when CAISO's CO2 to serve demand is below zero, driven by renewables, exports, and import accounting.

✅ Calculated using imports and exports to serve ISO demand

✅ Occur during high solar output, low weekend load

✅ Coincide with curtailment and record renewable penetration

 

We’re a long way from the land of milk and honey, but on Easter Sunday – for about an hour – we got a taste.

On Sunday, at 1:55 PM Pacific Time the California Independent Systems Operator (CAISO) reported that greenhouse gas emissions necessary to serve its demand (~80% of California’s electricity demand on an annual basis), was measured at a rate -16 metric tons of CO2 per hour. Five minutes later, the value was -2 mTCO2/h, before it crept back up to 40 mTCO2/h at 2:05 PM PST. At 2:10 PST though it fell back to -86 mTCO2/h and stayed negative until 3:05 PM PST, even as global CO2 emissions flatlined in 2019 according to the IEA.

This information was brought to the attention of pv magazine via tweet from eagle eye Jon Pa after CAISO’s site first noted the negative values:

The region was still generating CO2 though, as natural gas, biogas, biomass, geothermal and even coal plants were running and pumping out emissions, even as potent greenhouse gases declined in the US under control efforts. CAISO’s Greenhouse Gas Emission Tracking Methodology, December 28, 2016 (pdf) notes the below calculations to create the value what it terms, “Total GHG emissions to serve ISO demand”:

Of importance to note is that to get to the net negative value, CAISO considered all electricity imports and exports, a reminder that climate policy shapes grid operations across North America. And as can be noted in the image below the CO2 intensity of imports during the day rapidly declined as the sun came up, first going negative around 9:05 AM PST, and mostly staying so until just before 6 PM PST.

During this same weekend, other records were noted (reiterating that we’re in record setting season and as the state pursues its 100% carbon-free mandate now in law) such as a new electricity export record of greater than 2 GW and total renewable electricity as part of total demand at greater than 70%.

At the peak negative moment of 2:15 PM PST, -112 mTCO2/h seen below, the total amount of clean instantaneous generation being used in the power grid region was 17 GW, a far cry from heat-driven reliability strains like rolling blackout warnings that arise during extreme demand, with renewables giving 76% of the total, hydro 14%, nuclear 13% and imports of -12% countering the CO2 coming from just over 1.4 GW of gas generation.

Also of importance are a few layers of nuance in the electricity demand charts. First off we’re in the shoulder seasons  of California – nice cool weather before the warmth of summer drives air conditioning demand. Additional the weekend electricity demand is always lower, as well, Easter Sunday might have had an affect, whereas in colder regions Calgary’s electricity use can soar during frigid snaps.

Lastly to note was the amount of electricity from solar and wind generation being curtailed. And while the Sunday numbers weren’t available yet, the below image noted Saturday with 10 GWh in total being curtailed (pdf) – peaking at over 3.2 GW of instantaneous mostly solar power even as solar is now the cheapest electricity according to the IEA, in the hours of 2 and 3 PM PST. On an annualized basis, less than 2% of total potential solar electricity was curtailed in 2018.

 

 

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