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Tantalus Systems Holding Inc. (TSXV: GRID) Reports Strong Fourth Quarter & 2020 Year-End Results


Burnaby, BC – April 21, 2021 –– Smart grid technology leader Tantalus Systems Holding Inc. (TSXV: GRID) (“Tantalus”, “TSHI” or the “Company”) today announced the financial results for its wholly-owned subsidiary, TSH Canada Inc. (formerly known as Tantalus Systems Holding Inc.), for the fourth quarter and fiscal year ended December 31, 2020. The Company also announced that the Toronto Stock Exchange (“TSX”) has conditionally approved the listing of the Company’s shares. Listing is subject to the Company fulfilling all requirements of the TSX. The Company expects to satisfy the TSX’s requirements in the coming weeks.

“Considering the challenges witnessed throughout the course of 2020 due to the impact of the COVID-19 pandemic across our utility customers and their communities, our business partners, and our employees, Tantalus finished the year with strong revenues during the second half of 2020, higher gross profits year-over-year and delivered a fourth consecutive year of positive adjusted EBITDA. The financial results delivered during the latter portion of 2020 bode well for our company and demonstrate management’s ability to navigate through unforeseen challenges at a macro-level,” said Peter Londa, President & CEO of Tantalus. “While Tantalus continues to witness disruptions to the utility sector on a regional basis across Canada, the United States and the Caribbean Basin arising from the COVID-19 pandemic and is subject to the supply chain constraints for microprocessors being witnessed globally in 2021, our business conditions are improving with increasing tailwinds to support the Company’s long-term growth.”

As an example of the tailwinds that are anticipated to support long-term growth, the Biden Administration’s shift in environmental policy, highlighted by a goal of decarbonizing the power industry in the United States by 2050, will lead to a massive investment in both renewable sources of generation and necessary upgrades to the distribution grid to provide utilities with the ability to command and control assets from the substation to the meter and into buildings and residences. In support of the administration’s environmental policy, the recent announcement of a $2 trillion stimulus package includes funding for utilities to upgrade infrastructure in conjunction with the deployment and adoption of renewable energy (such as wind and large solar installations) and distributed energy resources (known as “DERs”, such as electric vehicles, roof-top solar panels and battery storage). As these new renewable sources of power are deployed, utilities will need to make upgrades to their distribution grids to plan for the variability of renewable energy, as witnessed in Texas during the winter storm earlier this year, and to fully integrate DERs into their grid.

CLICK HERE to read the full press release.


Integrated Energy Efficiency and Demand Flexibility: Promoting and Scaling Grid-Interactive Efficient Buildings (GEBs) 


Key practitioner perspectives needed...

Project Scope
The project focuses on how utility integrated energy efficiency/demand flexibility programs can promote grid-interactive efficient buildings (GEBs) by investigating successful projects, key learnings, existing business model challenges and regulatory barriers, and case studies.

Project Partners
SEPA is conducting this industry-leading study in partnership with Lawrence Berkeley National Laboratory (Berkeley Lab) and the U.S. Department of Energy’s (DOE) Building Technology Office. What’s Next & How You Can Participate SEPA will convene diverse experts for focus groups and interviews to:

  • Identify energy efficiency, demand response, and demand flexibility programs/pilots that may promote GEBs
  • Discuss successful projects, key learnings, and existing business model challenges and regulatory barriers
  • Explore the future of GEBs including perspectives on the role of the utility, solution providers, and regulators, and ways the industry can promote GEBs

Focus group discussions will be conducted under Chatham House Rule, with anonymized key learnings informing the study’s report to be published in late 2021. Additionally, the study will feature key utility case studies, which will be identified from focus group workshops for further interviews. Focus group participants will have the opportunity to:

  • Highlight their successful projects and findings that enable integrated energy efficiency, demand response, and demand flexibility programs,
  • Help the electric industry overcome existing business model challenges and regulatory barriers, and
  • Build a network to engage in peer-to-peer learning and discussion.

CLICK HERE for more information.


Meet the 18th PLMA Award Winners from 2021: 

PLMA proudly announced the winners of its 18th PLMA Awards. Those recognized by their peers for outstanding load management programs, initiatives, and achievements in calendar year 2020 included:


Program Pacesetters

  • Eversource Energy's ConnectedSolutions Program
  • Western Power's 100 MW Challenge (Australia)
  • Consumers Energy, Uplight, and Google Nest

Technology Pioneer

  • Enel X North America

Thought Leader 

  • The GridSavvy Community by Sonoma Clean Power

These award winners were recognized at the 43rd PLMA Conference, May 10-12, 2021. Each winning initiative was also featured in a PLMA Load Management Dialogue webinar/podcast. You can see the recordings for these webinars on PLMA's Load Management Resource Center. 

Click Here to Access Recordings from the 18th PLMA Award Winners' Webinar Presentations


Guidehouse Insights Leaderboard: Home Energy Management Providers


Assessment of Strategy and Execution for 15 Home Energy Management Solutions Providers

Home energy management (HEM) is a broad market of technologies and services with the primary purpose of providing information for homeowners to better manage and control their home energy consumption and production. Energy management has become an essential part of the digitization of the home, particularly for those who have invested in smart homes, acquired distributed energy resources (DER), or participated in power generation programs such as virtual power plants (VPP).

The information on energy use and production can come from monitors installed within the residence or be derived from smart meter reads. When the local utility works with an HEM vendor to analyze the usage information to prepare home energy reports, the utility is also able to obtain information that enables customer engagement (CE) programs to create highly customized programs. Such programs dramatically improve customer satisfaction scores, lower costs, and provide the data needed for demand side management (DSM) programs that assist in the transition to more renewable energy.

CLICK HERE to read more or purchase the report.

PLMA Members receive a 10% discount on this report. If you are interested in purchasing and are a PLMA member, contact Brett Feldman at [email protected].


Hawaii Groups Push for Demand-side Measures, Streamlined Interconnection to Manage Coal Plant Closure


The Hawaii Public Utilities Commission (PUC) should turn to customer-side solutions like demand response, energy efficiency and distributed energy resources, as well as streamline interconnection processes to prepare for the retirement of a 180 MW coal plant in Oahu, several parties recommended in comments last week.

Regulators in the state are concerned that delays to a series of renewables projects could force Hawaiian Electric (HECO) to rely on fossil fuel generation after the plant retires in 2022. Last month, the commission opened a rulemaking to review HECO's interconnection processes and plans for that transition.

HECO plans to retire two fossil fuel plants in the next few years that currently play a key role in grid reliability — the Oahu coal plant, which serves around 15% of demand on Oahu, as well as the 38 MW oil-fired Kahului plant on Maui, which is scheduled to close down in 2024. The utility also intends to shutter two units of an oil-fired plant in Waiau, also on Oahu, as soon as possible.

HECO plans to replace these plants with a combination of solar and storage resources, including the 185 MW Kapolei energy storage project, which is supposed to come online in summer 2022. But regulators are worried about delays to many of these projects, which stakeholders say are caused by HECO's interconnection processes. And because the Kapolei project is scheduled to come online before the others — pending regulatory approval — it would initially charge off fossil fuel generation, another area of concern for the commission.

In comments filed with the PUC last week, some parties pointed to demand-side solutions that could help address potential shortfalls after the plants' closures. Automated demand response programs especially could both help stabilize the grid and reduce customers bills, GridPoint, an energy efficiency and demand response provider, said in comments. GridPoint can currently provide between 4 kW and 50 kW of on-demand capacity for each of the commercial sites it manages for up to four-hour periods; but if required, the company said it could increase that to 8 kW to 80 kW for shorter periods ranging from 15 minutes to an hour.

CLICK HERE to the full article.

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