Energy Storage
Brian Cashion
Energy Storage
Accure Battery Intelligence
Energy Storage
Jim Brown
Stationary battery manufacturer Hithium and Maxxen, a 100 percent subsidiary of Kontek Energy, which has 30 years of energy industry experience have announced their exclusive strategic partnership at the Türkiye launch of this cooperation on May 17, 2024, in Istanbul, Türkiye.
Hithium and Maxxen have joined forces in an exclusive strategic partnership agreement in the field of energy storage for the battery energy storage system and the trademark rights of Hithium. This will result in the creation of more sustainable energy systems globally and locally.
As Hithium GM of the Middle East region and Head of Global Delivery Centre, Sean Sun commented: “It's very promising to cooperate with Maxxen to contribute to energy transition with both parties in Türkiye. This bonding relationship will enhance our market competitiveness and together dedicate to the needs of affordable, reliable and flexible energy storage solution.”
As Maxxen & Kontek CEO, Tolga Murat Özdemir commented: “We, at Maxxen, believe that cooperating with Hithium as one of the leading manufacturer of BESS Systems in the world focused only in Stationary Energy Storage, will help create a synergy to expand the business of two companies around the region not only by being closer to the projects to supply shorter deliveries and better after sale services with outstanding quality and manufacturing processes but at the same time using the capabilities of Maxxen in contributive digital solutions will also help develop value added derivative complete solutions to the related markets.”
This partnership between Hithium and Maxxen represents an important step towards a cleaner future. The objective is to play a key role in making a difference in the energy storage sector by establishing a battery energy storage systems production facility in Türkiye. In furtherance of the aforementioned agreement, the two companies have agreed that they will endeavor to develop groundbreaking innovations in the field of sustainable energy. Hithium and Maxxen are committed to contributing to the worldwide energy transition by accelerating the spread of battery energy storage technologies to wider audiences.
Hithium | https://hithium.com/en/
Babcock & Wilcox (B&W) (NYSE: BW) announcedtoday that Babcock & Wilcox Construction Co., LLC (BWCC) has been awarded U.S. power plant outage and rebuild work valued at more than $20 million.
“Keeping the existing baseload power fleet operating is critical to energy security, reliability and affordability, and demand for plant maintenance services remains strong as plant owners recognize the importance of extending the operating life of their power generating assets and keeping them running at maximum efficiency,” said BWCC Vice President and General Manager Mike Hidas.
“These outage and rebuild work agreements also drive increased demand for replacement parts,” Hidas said. “B&W is a trusted provider of replacement parts for B&W and competitors’ equipment, including a wide range of power plant, boiler, auxiliary and environmental equipment.”
BWCC provides outage services, installation, refurbishment, mechanical repair and maintenance services for a variety of industries – including utilities, oil and gas, petrochemical, pulp and paper and others – as well as equipment and plant installations, regardless of the original manufacturer.
Babcock & Wilcox Enterprises | babcock.com
Valmet has announced the appointment of Rocky Matuska as Vice President, Services, North America. Matuska’s appointment will become effective on August 1, 2024. In his new role, Matuska will be responsible for leading and managing all Valmet Services operations in North America. He will also become a member of the North America Area Management Team (AMT).
Matuska is currently Director, Sales & Technology, Paper and Board, North America Capital Business at Valmet. He is based in Valmet’s Beloit, WI, facility and will remain there following his appointment. He will succeed Kari Lindberg, Sr. Vice President, Services, North America, who will retire in early 2025.
Matuska holds a Bachelor of Science degree in mechanical engineering and has over 30 years of experience in the pulp and paper industry. His proven track record of success in the industry includes engineering positions for Beloit Corporation and PMP Americas. Matuska also played an integral role in integrating the small and medium-size equipment (SMM) business into the Valmet North America portfolio.
Valmet | valmet.com
Fermata Energy, Xcel Energy, City of Boulder, Colorado CarShare and Boulder Housing Partners announced a collaborative Vehicle-to-Everything (V2X) bidirectional charging pilot project at Boulder Housing Partners’ 30 Pearl development and the Molly's Spirits Lakeside facility. This innovative V2X pilot program transforms parked EVs into mobile power units, advancing grid resilience and reducing electric bill costs while supporting underserved communities and local businesses.
Fermata Energy's intelligent bidirectional charging platform paired with four (4) FE-20 chargers and two (2) of Colorado CarShare’s Nissan LEAFs will showcase V2X and Vehicle-to-Building (V2B) technology's untapped potential. When an electric vehicle is parked and in V2X mode, the Fermata Energy platform leverages the vehicle’s battery energy to offset and lower the building’s peak demand. Fermata Energy’s Demand Charge Management (DCM) software intelligence manages the total system power and energy via charge rate, frequency and depth while intelligently preserving the vehicle's battery health. This technology is designed to optimize customer value by curtailing building peak demand at the same time preserving needed range for the expected electric vehicle duty cycle.
"We're on the cusp of a transformative era in energy management, where electric vehicles transcend their traditional transportation roles to become pivotal in increasing grid resilience and sustainability," Tony Posawatz, CEO of Fermata Energy, stated. "This collaboration with Xcel Energy is more than a project; it's a blueprint for an attainable global renewable energy ecosystem.”
“This program helps deliver the benefits of electric vehicles to all customers in the communities we serve, including those that don’t drive, or drive electric. This project is a proof of concept of bi-directional charging, to assess technology with the potential to enhance customer bill savings,” said Huma Seth, Director of Clean Transportation at Xcel Energy. “We know EVs can help customers save money on their transportation costs and they deliver cleaner air for everyone because they are powered with increasingly clean electricity.”
Beyond these newest deployments, Fermata Energy's V2X impact is notable. Since December 2020, the City of Boulder has leveraged Fermata Energy's V2B technology at the North Boulder Recreation Center, achieving energy cost savings and reinforcing the city's renewable energy and sustainability commitment. The Alliance Center, with Colorado CarShare, launched a V2B project, illuminating electric carsharing and grid technology synergy to address climate change effectively in one of Denver's historic buildings. Fermata Energy also launched a Vehicle-to-Grid (V2G) pilot program for multi-family affordable housing to increase affordable access to EVs for low-income drivers in Boston.
The collaboration between Fermata Energy, Xcel Energy, City of Boulder, Colorado CarShare and Boulder Housing Partners demonstrates a practical application to scale V2X technology deployments within Xcel Energy's service territory, marking a significant step forward in the integration of electric vehicles with the energy grid for enhanced resilience and efficiency.
Fermata Energy | https://fermataenergy.com/
Xcel Energy | xcelenergy.com
Colorado Carshare | carshare.org
Agrivoltaics, the innovative practice of co-locating agriculture and photovoltaic (PV) systems, is revolutionizing sustainable land use and energy production. By harnessing the synergy between agriculture and solar energy, agrivoltaics offers a transformative solution to address the challenges of food security, water scarcity, and climate change. This editorial explores the burgeoning agrivoltaics market, its potential benefits, challenges, and future outlook.
The Concept of Agrivoltaics:
Agrivoltaics, also known as dual-use solar agriculture, involves the simultaneous cultivation of crops or livestock alongside PV panels on the same land. This integrated approach optimizes land use efficiency by maximizing the utilization of sunlight for both food production and electricity generation.
Agrivoltaic systems can range from simple setups, such as raised solar panels allowing crops to grow beneath, to more complex designs incorporating advanced irrigation, shade management, and crop selection strategies.
Benefits of Agrivoltaics:
Challenges and Considerations:
Future Outlook and Opportunities:
Conclusion
In conclusion, agrivoltaics represents a paradigm shift in the way we utilize land resources, produce food, and generate renewable energy. By harnessing the power of synergy between agriculture and solar energy, agrivoltaic systems offer a multifaceted solution to address the interconnected challenges of food security, energy access, and environmental sustainability.
As the agrivoltaics market continues to evolve and mature, it is imperative to foster collaboration, innovation, and policy support to unlock its full potential and create a more resilient, equitable, and sustainable future for generations to come.
Transparency Market Research | www.transparencymarketresearch.com
Technology group Wärtsilä will supply the Caribbean island of Curaҫao with a 25 MW / 25 MWh Battery Energy Storage System (BESS). The system will enable the expansion of renewable energy capacity and the reduction of carbon emissions, representing an important step towards a sustainable energy future for the island. The order was placed by Aqualectra, Curacao’s government owned utilities company, and will be booked by Wärtsilä in Q2, 2024.
The BESS and the GEMS Digital Energy Platform will provide grid stability and reliability, reduce unserved energy and help mitigate the risk of brownouts and blackouts. In addition, the BESS system will allow Aqualectra to expand their renewables’ vision thus allowing more renewable generation in the power system. The BESS system will also help smooth the intermittency of renewables.
"Aqualectra’s strategic objective is to provide the community with affordable, sustainable, and reliable electricity. The Wärtsilä solution will support all these objectives through reducing generation costs, enabling the integration of renewables, and decreasing CO2 emissions, while providing high reliability," comments Joseph Everon, Advisor to the CTO at Aqualectra.
The order with Wärtsilä follows a detailed modelling of the power system to determine the best way forward.
"The BESS and GEMS provide the reserves needed to improve asset loading, and therefore efficiency, availability of energy, grid stability and reliability. Wärtsilä’s leading technologies and our capabilities of lifecycle services will support Aqualectra’s vision of a sustainable energy future. We are pleased to continue our close partnership with this project," says Christoffer Ek, Director of Decarbonisation services at Wärtsilä Energy.
"The Caribbean has been an important region for Wärtsilä for decades and we have established many long-term relationships over that time. Aqualectra has been one of those great partners and this announcement to add BESS to their system with Wärtsilä is another sign of that strong relationship. Wärtsilä is here with solutions and capabilities for the Caribbean, and we are excited to continue serving this market for decades to come," says Jon Rodriguez, Energy Business Director at Wärtsilä Energy.
The Wärtsilä equipment is scheduled for delivery in Q1/2025, and the project is expected to be fully operational by the end of Q2/2025.
Aqualectra is an existing Wärtsilä customer. The company operates three Wärtsilä engine power plants comprising a total of 16 generating sets.
Wärtsilä Energy | www.wartsila.com/energy
SolarEdge Technologies, Inc. (“SolarEdge” or the “Company”) (NASDAQ: SEDG), a global leader in smart energy technology, announced the release of its 2023 Sustainability Report, detailing the progress made in the Company’s sustainability strategy in the Environment, Society, Governance (ESG) fields and representing its commitment to accountability and transparency to stakeholders.
Zvi Lando, Chief Executive Officer of SolarEdge: “Today’s release of our 2023 Sustainability Report highlights the significant advancements we made toward our corporate ESG goals in 2023. We are deeply committed to accelerating the move to a low-carbon world and will continue to make progress on our path to enhance our corporate ESG practices. Our Sustainability Report details the many ways in which we deliver on our promise to power the future of energy through our products, people and business practices.”
Some of the key highlights from the 2023 Sustainability Report include:
View SolarEdge’s full 2023 Sustainability Report
SolarEdge | www.solaredge.com
Alternative Energies Jun 26, 2023
Unleashing trillions of dollars for a resilient energy future is within our grasp — if we can successfully navigate investment risk and project uncertainties. The money is there — so where are the projects? A cleaner and more secure energy ....
The Kincardine floating wind farm, located off the east coast of Scotland, was a landmark development: the first commercial-scale project of its kind in the UK sector. Therefore, it has been closely watched by the industry throughout its installation. With two of the turbines now having gone through heavy maintenance, it has also provided valuable lessons into the O&M processes of floating wind projects.
In late May, the second floating wind turbine from the five-turbine development arrived in the port of Massvlakte, Rotterdam, for maintenance. An Anchor Handling Tug Supply (AHTS)
vessel was used to deliver the KIN-02 turbine two weeks after a Platform Supply Vessel (PSV) and AHTS had worked to disconnect the turbine from the wind farm site. The towing vessel became the third vessel used in the operation.
This is not the first turbine disconnected from the site and towed for maintenance. In the summer of 2022, KIN-03 became the world’s first-ever floating wind turbine that required heavy maintenance (i.e. being disconnected and towed for repair). It was also towed from Scotland to Massvlakte.
Each of these operations has provided valuable lessons for the ever-watchful industry in how to navigate the complexities of heavy maintenance in floating wind as the market segment grows.
The heavy maintenance process
When one of Kincardine’s five floating 9.5 MW turbines (KIN-03) suffered a technical failure in May 2022, a major technical component needed to be replaced. The heavy maintenance strategy selected by the developer and the offshore contractors consisted in disconnecting and towing the turbine and its floater to Rotterdam for maintenance, followed by a return tow and re-connection. All of the infrastructure, such as crane and tower access, remained at the quay following the construction phase. (Note, the following analysis only covers KIN-03, as details of the second turbine operation are not yet available).
Comparing the net vessel days for both the maintenance and the installation campaigns at this project highlights how using a dedicated marine spread can positively impact operations.
For this first-ever operation, a total of 17.2 net vessel days were required during turbine reconnection—only a slight increase on the 14.6 net vessel days that were required for the first hook-up operation performed during the initial installation in 2021. However, it exceeds the average of eight net vessel days during installation. The marine spread used in the heavy maintenance operation differed from that used during installation. Due to this, it did not benefit from the learning curve and experience gained throughout the initial installation, which ultimately led to the lower average vessel days.
The array cable re-connection operation encountered a similar effect. The process was performed by one AHTS that spent 10 net vessel days on the operation. This compares to the installation campaign, where the array cable second-end pull-in lasted a maximum of 23.7 hours using a cable layer.
Overall, the turbine shutdown duration can be broken up as 14 days at the quay for maintenance, 52 days from turbine disconnection to turbine reconnection, and 94 days from disconnection to the end of post-reconnection activities.
What developers should keep in mind for heavy maintenance operations
This analysis has uncovered two main lessons developers should consider when planning a floating wind project: the need to identify an appropriate O&M port, and to guarantee that a secure fleet is available.
Floating wind O&M operations require a port with both sufficient room and a deep-water quay. The port must also be equipped with a heavy crane with sufficient tip height to accommodate large floaters and reach turbine elevation. Distance to the wind farm should also be taken into account, as shorter distances will reduce towing time and, therefore, minimize transit and non-productive turbine time.
During the heavy maintenance period for KIN-03 and KIN-02, the selected quay (which had also been utilized in the initial installation phase of the wind farm project), was already busy as a marshalling area for other North Sea projects. This complicated the schedule significantly, as the availability of the quay and its facilities had to be navigated alongside these other projects. This highlights the importance of abundant quay availability both for installation (long-term planning) and maintenance that may be needed on short notice.
At the time of the first turbine’s maintenance program (June 2022), the North Sea AHTS market was in an exceptional situation: the largest bollard pull AHTS units contracted at over $200,000 a day, the highest rate in over a decade.
During this time, the spot market was close to selling out due to medium-term commitments, alongside the demand for high bollard pull vessels for the installation phase at a Norwegian floating wind farm project. The Norwegian project required the use of four AHTS above a 200t bollard pull. With spot rates ranging from $63,000 to $210,000 for the vessels contracted for Kincardine’s maintenance, the total cost of the marine spread used in the first repair campaign was more than $4 million.
Developers should therefore consider the need to structure maintenance contracts with AHTS companies, either through frame agreements or long-term charters, to decrease their exposure to spot market day rates as the market tightens in the future.
While these lessons are relevant for floating wind developers now, new players are looking towards alternative heavy O&M maintenance options for the future. Two crane concepts are especially relevant in this instance. The first method is for a crane to be included in the turbine nacelle to be able to directly lift the component which requires repair from the floater, as is currently seen on onshore turbines. This method is already employed in onshore turbines and could be applicable for offshore. The second method is self-elevating cranes with several such solutions already in development.
The heavy maintenance operations conducted on floating turbines at the Kincardine wind farm have provided invaluable insights for industry players, especially developers. The complex process of disconnecting and towing turbines for repairs highlights the need for meticulous planning and exploration of alternative maintenance strategies, some of which are already in the pipeline. As the industry evolves, careful consideration of ports, and securing fleet contracts, will be crucial in driving efficient and cost-effective O&M practices for the floating wind market.
Sarah McLean is Market Research Analyst at Spinergie, a maritime technology company specializing in emission, vessel performance, and operation optimization.
Spinergie | www.spinergie.com
According to the Energy Information Administration (EIA), developers plan to add 54.5 gigawatts (GW) of new utility-scale electric generating capacity to the U.S. power grid in 2023. More than half of this capacity will be solar. Wind power and battery storage are expected to account for roughly 11 percent and 17 percent, respectively.
A large percentage of new installations are being developed in areas that are prone to extreme weather events and natural disasters (e.g., Texas and California), including high wind, tornadoes, hail, flooding, earthquakes, wildfires, etc. With the frequency and severity of many of these events increasing, project developers, asset owners, and tax equity partners are under growing pressure to better understand and mitigate risk.
Figure 1. The history of billion-dollar disasters in the United States each year from 1980 to 2022 (source: NOAA)
In terms of loss prevention, a Catastrophe (CAT) Modeling Study is the first step to understanding the exposure and potential financial loss from natural hazards or extreme weather events. CAT studies form the foundation for wider risk management strategies, and have significant implications for insurance costs and coverage.
Despite their importance, developers often view these studies as little more than a formality required for project financing. As a result, they are often conducted late in the development cycle, typically after a site has been selected. However, a strong case can be made for engaging early with an independent third party to perform a more rigorous site-specific technical assessment. Doing so can provide several advantages over traditional assessments conducted by insurance brokerage affiliates, who may not possess the specialty expertise or technical understanding needed to properly apply models or interpret the results they generate. One notable advantage of early-stage catastrophe studies is to help ensure that the range of insurance costs, which can vary from year to year with market forces, are adequately incorporated into the project financial projections.
The evolving threat of natural disasters
Over the past decade, the financial impact of natural hazard events globally has been almost three trillion dollars. In the U.S. alone, the 10-year average annual cost of natural disaster events exceeding $1 billion increased more than fourfold between the 1980s ($18.4 billion) and the 2010s ($84.5 billion).
Investors, insurers, and financiers of renewable projects have taken notice of this trend, and are subsequently adapting their behavior and standards accordingly. In the solar market, for example, insurance premiums increased roughly four-fold from 2019 to 2021. The impetus for this increase can largely be traced back to a severe storm in Texas in 2019, which resulted in an $80 million loss on 13,000 solar panels that were damaged by hail.
The event awakened the industry to the hazards severe storms present, particularly when it comes to large-scale solar arrays. Since then, the impact of convective weather on existing and planned installations has been more thoroughly evaluated during the underwriting process. However, far less attention has been given to the potential for other natural disasters; events like floods and earthquakes have not yet resulted in large losses and/or claims on renewable projects (including wind farms). The extraordinary and widespread effect of the recent Canadian wildfires may alter this behavior moving forward.
A thorough assessment, starting with a CAT study, is key to quantifying the probability of their occurrence — and estimating potential losses — so that appropriate measures can be taken to mitigate risk.
All models are not created equal
Industrywide, certain misconceptions persist around the use of CAT models to estimate losses from an extreme weather event or natural disaster.
Often, the perception is that risk assessors only need a handful of model inputs to arrive at an accurate figure, with the geographic location being the most important variable. While it’s true that many practitioners running models will pre-specify certain project characteristics regardless of the asset’s design (for example, the use of steel moment frames without trackers for all solar arrays in a given region or state), failure to account for even minor details can lead to loss estimates that are off by multiple orders of magnitude.
The evaluation process has recently become even more complex with the addition of battery energy storage. Relative to standalone solar and wind farms, very little real-world experience and data on the impact of extreme weather events has been accrued on these large-scale storage installations. Such projects require an even greater level of granularity to help ensure that all risks are identified and addressed.
Even when the most advanced modeling software tools are used (which allow for thousands of lines of inputs), there is still a great deal that is subject to interpretation. If the practitioner does not possess the expertise or technical ability needed to understand the model, the margin for error can increase substantially. Ultimately, this can lead to overpaying for insurance. Worse, you may end up with a policy with insufficient coverage. In both cases, the profitability of the asset is impacted.
Supplementing CAT studies
In certain instances, it may be necessary to supplement CAT models with an even more detailed analysis of the individual property, equipment, policies, and procedures. In this way, an unbundled risk assessment can be developed that is tailored to the project. Supplemental information (site-specific wind speed studies and hydrological studies, structural assessment, flood maps, etc.) can be considered to adjust vulnerability models.
This provides an added layer of assurance that goes beyond the pre-defined asset descriptions in the software used by traditional studies or assessments. By leveraging expert elicitations, onsite investigations, and rigorous engineering-based methods, it is possible to discretely evaluate asset-specific components as part of the typical financial loss estimate study: this includes Normal Expected Loss (NEL), also known as Scenario Expected Loss (SEL); Probable Maximum Loss (PML), also known as Scenario Upper Loss (SUL); and Probabilistic Loss (PL).
Understanding the specific vulnerabilities and consequences can afford project stakeholders unique insights into quantifying and prioritizing risks, as well as identifying proper mitigation recommendations.
Every project is unique
The increasing frequency and severity of natural disasters and extreme weather events globally is placing an added burden on the renewable industry, especially when it comes to project risk assessment and mitigation. Insurers have signaled that insurance may no longer be the main basis for transferring risk; traditional risk management, as well as site and technology selection, must be considered by developers, purchasers, and financiers.
As one of the first steps in understanding exposure and the potential capital loss from a given event, CAT studies are becoming an increasingly important piece of the risk management puzzle. Developers should treat them as such by engaging early in the project lifecycle with an independent third-party practitioner with the specialty knowledge, tools, and expertise to properly interpret models and quantify risk.
Hazards and potential losses can vary significantly depending on the project design and the specific location. Every asset should be evaluated rigorously and thoroughly to minimize the margin for error, and maximize profitability over its life.
Chris LeBoeuf is Global Head of the Extreme Loads and Structural Risk division of ABS Group, based in San Antonio, Texas. He leads a team of more than 60 engineers and scientists in the US, UK, and Singapore, specializing in management of risks to structures and equipment related to extreme loading events, including wind, flood, seismic and blast. Chris has more than 20 years of professional experience as an engineering consultant, and is a recognized expert in the study of blast effects and blast analysis, as well as design of buildings. He holds a Bachelor of Science in Civil Engineering from The University of Texas at San Antonio, and is a registered Professional Engineer in 12 states.
ABS Group | www.abs-group.com
Grid modernization is having a profound impact on the nature and regulation of North American utilities. It represents a significant change to the way energy is managed, distributed, and used—today and in the future. As Environmental, Social, and Governance (ESG) targets become increasingly important to energy investors and regulators, how can organizations transform their Asset Investment Planning (AIP) processes to overcome challenges and take advantage of emerging opportunities?
Grid modernization
The energy transition refers to the global energy sector’s shift from fossil-based systems of energy production and consumption to renewable energy sources like wind and solar, as well as long-term energy storage such as batteries. The increasing penetration of renewable energy into the energy supply mix and the onset of electrification and improvements in energy storage are key drivers of the energy transition.
Grid modernization is a subset of the energy transition, and refers to changes needed in the electric transmission and distribution (T&D) systems to accommodate these rapid and innovative technological changes. Grid modernization often necessitates the increased application of sensors, computers, and communications to increase the intelligence of the grid and its ability to respond swiftly to external factors. The main goals of the grid are to provide the capacity, reliability, and flexibility needed to adapt to a whole range of new technologies (in the drive to net zero), while maintaining a comparable level of service and cost to the end customer.
Grid modernization projects are driven by both climate resilience through hardening of assets and changes to the T&D network to accommodate climate mitigation strategies. There are 3 broad categories for these types of projects:
Grid modernization is accelerating due to multiple factors, such as decarbonization, electrification, extreme weather, and security threats.
Valuing innovative projects
The changing demands dictated by grid modernization will require organizations to strike the right balance between cost-effectively managing the current business, while investing appropriately to meet future demands. Organizations are already seeing an increase in both the volume and variety of grid modernization projects. This is leading to increased planning complexity, requiring utilities to demonstrate that they are spending their limited budgets and resources to maximize value and drive their ESG and performance targets.
A value-based approach to investment decision making is key to establishing a common basis to evaluate potential investment opportunities and meet the challenges of grid modernization. The key to achieving your organization’s grid modernization goals is building a multi-year plan that breaks the work into executable chunks. This ensures adequate funding and resources are available to carry out the plan in the short-term, resulting in incremental progress toward longer-term objectives.
With a value-based decision-making approach, organizations can ensure they are making the right grid modernization investments—and justify their plans to internal and external stakeholders.
Align decisions with strategic objectives
Business leaders must develop frameworks that quantify the financial and non-financial benefits of all proposed investments on a common scale and understand how projects will contribute to their short- and long-term grid modernization initiatives and broader energy transition goals. A value framework also creates a clear line of sight from planned investments to regulatory and corporate targets, allowing organizations to provide transparency into the decision-making methodology—and demonstrate the benefits of their plans to regulators, stakeholders, and customers:
Russ is a Director of Product Management, Decision Analytics at Copperleaf. He is an innovative leader with over 20 years of comprehensive business and technical experience in high-tech product development organizations. Russ holds a B.A.Sc. in Mechanical Engineering from the University of British Columbia and a Management of Technology MBA from Simon Fraser University.
Copperleaf | www.copperleaf.com
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