With support from Alberta Innovates’ Hydrogen Centre of Excellence program, InnoTech Alberta and C-FER Technologies are helping industry integrate hydrogen in the global energy system. Martin Huard (InnoTech) and Brian Wagg (C-FER) will provide updates on the new testing capabilities that have been installed and the leading-edge testing programs that are addressing key aspects of Alberta’s Hydrogen Roadmap. The following projects will be reviewed:H2 production from maturing thermal oil reservoirs and low-value by-products of bitumen productionNatural H2 exploration in AlbertaDeveloping valuable applications for solid carbon from methane pyrolysisEvaluating the feasibility of converting natural gas pipelines and underground storage assets to hydrogen serviceValidating the performance of pipeline leak detection systems for blends of hydrogen and natural gasQualifying equipment for use in underground hydrogen storage wells

Martin HuardHydrogen LeadInnoTech Alberta

Brian WaggDirector, Business Development and Strategic InitiativesC-FER Technologies

On-site hydrogen production for fuel use has been identified as a strategic decarbonization pathway for compressor stations with no nearby grid access, no hydrogen infrastructure and no adjacent geology formation or infrastructure to store CO2. Methane pyrolysis, which has emerged as an attractive process as it utilizes methane, to produce hydrogen and a by-product of carbon black (solid carbon). Furthermore, methane pyrolysis doesn’t require any process water, which makes it attractive in the areas where water resources is limited. Combining the features of both pyrolysis and hydrogen combustion offers additional opportunities for heat and integration, as well as offsetting additional parasitic electrical loads. By using natural gas from TCE’s existing natural gas pipelines, methane pyrolysis takes advantage of the infrastructure already in place at compressor stations, decarbonizing the transportation of natural gas at hard to abate locations.TCE Energy will present the results of a preliminary front end engineering design study that evaluated thermal methane pyrolysis production, integrated with compressor station turbo-machinery. The presentation will address the challenges and opportunities of methane pyrolysis as a decarbonization pathway and highlight the approach to integrating the energy needs, turbine modifications, solid carbon management and operational modifications to using hydrogen as a fuel gas for compressor stations. This project is supported by Alberta Innovates (AI) Hydrogen Centre of Excellence (HCOE) funding.

Dave RichardsProject Manager – HydrogenTC Energy

Peter GribaSenior Technical Specialist, Climate Targets & StrategyTC Energy

ATCO Gas and Pipelines Ltd. (ATCO) and Qualico, through partnerships with Alberta Innovates and the Government of Canada, have undertaken a demonstration in Sherwood Park, Alberta to commission North America’s first 100% hydrogen home, HomeOne. In alignment with Canada’s net-zero by 2050 goal, this project showcases that utilizing hydrogen is a feasible solution for the decarbonization of home space and water heating, particularly in Alberta’s harsh climate. This project involved the design, procurement, construction and commissioning of a residential hydrogen home from source to burner tip. This included a 100% hydrogen virtual pipeline supply, pressure regulation, instrumentation and controls, service line, metering, house piping and end use appliances. The first of its’ kind nature of the project had ATCO executing on a large-scale change management program encompassing a full review of company practices and external engagement to ensure the safe and reliable execution of Home One. Additionally, ATCO worked towards defining design and operational parameters that can be easily replicated on a broad scale, as ATCO and Qualico move towards completing a front-end engineering and design (FEED) study for a 100% hydrogen community in Strathcona County, Alberta.This paper explores the execution of Home One, from design concept to execution and the lessons learned throughout the project lifecycle. 

Curtis MeunierSenior EngineerATCO Gas & Pipelines

Over the past decade, Emissions Reduction Alberta and Alberta Innovates, two cleantech innovation agencies funded by the Government of Alberta, have collectively invested more than $125M CAD in hydrogen projects with a total value approaching $2B CAD. These investments span the hydrogen value chain of production, transportation, storage, and end-use, as well as technology readiness levels 3 (experimental) to full commercial scale Now, most of these new technologies are maturing, and the results of the government-supported investment projects can inform the future potential of hydrogen as a net zero pathway. The objective of this presentation is to provide an assessment of Alberta government funding agencies’ significant investments in hydrogen to date, with the goal of informing future adoption of hydrogen. Technologies will be assessed in terms of readiness for commercialization, relative cost and performance compared to competitors, emissions reduction potential, lifecycle impacts, barriers to broader adoption, technology transfer potential, and other criteria. Metrics collected from proponents such as estimated production cost, delivery cost, and lifecycle emissions intensity will be shared. The projects will be assessed across the three main areas of the hydrogen value chain: production, storage & transportation, and end-use. Key findings to be discussed in the presentation include: Production: Hydrogen may be produced at low cost using natural gas feedstock and carbon capture and storage, but requires attention to upstream methane footprint, source of energy, water usage, and geography. Methane pyrolysis and electrolysis may become more competitive for smaller, distributed applications, but also face environmental, cost, and scaling challenges. Storage & transportation: Getting hydrogen from the production site to the end-user forms a significant portion of the cost of this fuel, often greater than the cost of production. Local distribution of hydrogen at scale can be done at competitive cost to diesel for certain applications. Shipping of hydrogen over long distances remains a significant challenge. Most hydrogen carriers remain at a relatively low readiness. End-Use: For heavy freight applications in cold climates such as Alberta’s, hydrogen fuel cell vehicles (HFCVs) and dual-fuel hydrogen-diesel vehicles significantly outperform electric vehicles (EVs). For light duty vehicles, EVs perform well at lower cost. Dual-fuel vehicles are not zero-emitting, but can be retrofitted and may be lower cost than HFCVs. Investments across these areas have built upon Alberta’s expertise as one of the lowest cost producers of hydrogen in the world. Given this positioning, these projects’ collective learnings provide value for knowledge sharing with other jurisdictions considering adoption of hydrogen, as well as opportunities for technology transfer and collaboration.

Jennifer Chen GHG Impact Quantification LeadEmissions Reduction Alberta

The transition to a sustainable energy future hinges significantly on the development of green hydrogen production facilities using electrolysers and other electrical technologies. ABB has served most industries and helped craft thousands of world class facilities using a myriad of electrical equipment. This abstract explores the critical role of electrical solutions within the green hydrogen value chain, emphasizing the design and optimization of hydrogen electrolyzer power supplies. Key priorities in hydrogen rectifier design include achieving high efficiency and minimizing lifecycle power costs, which are essential for the economic viability of green hydrogen production.System design selection rules are outlined to guide the development of robust and efficient rectifiers, focusing on optimizing product cost, size and efficiency. Creating an efficient production factory has many important considerations that need to be addressed to deliver the required uptime. Additionally, system considerations such as thermal management, reliability, and integration with renewable energy sources are discussed. The carbon footprint of rectifiers is also analyzed, highlighting the importance of low-emission, long service life designs in reducing the overall environmental impact of green hydrogen production.By addressing these priorities and considerations, this presentation aims to provide a comprehensive overview of the electrical solutions necessary for advancing the green hydrogen production plant, ultimately contributing to a more sustainable, profitable and carbon-neutral facility.

Roger DorselHydrogen North America Product Group LeadABB Inc.

Enbridge Gas (EGI) is leading the integration of hydrogen into North America's energy sector to help meet global greenhouse gas (GHG) reduction goals. A key milestone in this journey is the Markham pilot project, which supplies over 3600 customers with 2% hydrogen-blended natural gas. Building on this success, the Enbridge Gaz Quebec led hydrogen initiative, supported by EGI, represents the next phase in advancing hydrogen adoption. The Enbridge Gaz Quebec distribution network consists of vintage steel and PE pipelines (installed from 1956 to 2021), as well as cast fittings, meters, regulators, and end-user equipment, all initially designed for natural gas.Therefore, validation is essential before introducing hydrogen into the network. Currently, Canada lacks specific guidelines for hydrogen-blended gas, but CSA Z662-23 mandates a detailed engineering assessment before integrating hydrogen into existing natural gas networks. To ensure the safe transition to hydrogen blended natural gas, Enbridge Gaz Quebec conducted a comprehensive engineering assessment of the affected network.This presentation will outline Enbridge’s approach to identifying the challenges associated with hydrogen blending and share key findings from the ongoing Engineering Assessment (EA) process. It will focus on technical gaps uncovered during the assessment, EGI's initiatives to resolve these challenges, and the ongoing pipe and fitting testing projects. Additionally, the presentation will cover the next steps needed to ensure the safe and reliable integration of hydrogen into the Enbridge Gaz Quebec network.In conclusion, EGI's thorough evaluation framework and collaborative research will provide a solid foundation for hydrogen integration within the Enbridge Gaz Quebec network and beyond. By advancing the understanding of hydrogen’s impact on gas infrastructure and developing clear pathways for its safe adoption, EGI’s initiatives are playing a critical role in driving the energy transition. The insights gained from this Engineering Assessment will also benefit the broader hydrogen community in adapting existing natural gas networks for hydrogen or blended service.

Tahrim AlamSenior EngineerEnbridge Gas

Increasingly driven by efforts to reduce greenhouse gas (GHG) and investments in hydrogen (H2) generation, storage, and distribution, large commercial and industrial (C&I) utility customers are beginning to investigate how H2-based fuels can be adopted by their boilers and process heating equipment. Across multiple research, development & demonstration (RD&D) projects, GTI Energy and its partners are investigating the operational limits and impacts of operating C&I equipment designed for natural gas, including boilers, industrial furnaces, and other process heating equipment, with H2-based fuels. As a completement to recent GTI publications summarizing the opportunities and impacts of H2-based fuels on residential and light commercial appliances, this presentation provides the same for larger C&I equipment.Through an expansive laboratory research program, this presentation covers recent findings from testing and demonstrating C&I equipment, including boilers and process heating equipment, operating equipment two ways with natural gas to near 100% H2, up to the point of observed issues with combustion stability: 1) setting the equipment for natural gas and incrementally increasing the hydrogen blend from there and 2) setting the equipment for natural gas and, as the hydrogen blend ratio increases, constantly adjusting to maintain a constant heating output. Data across multiple examples of each technology category (boilers, commercial water heating, industrial furnaces, direct-fired process heaters/ovens/kilns, etc.) will be reviewed concerning performance & process impacts, efficiency, NOx/CO emissions, CH4/H2 slip, leakage enhancement, and other factors (noise, etc.). As upper stability limits with H2 blend ratios are examined, primarily via flashback or delayed ignition, opportunities for adjusting operating parameters or small modifications to equipment are examined to adopt higher H2 blends. These controlled laboratory testing results are put into context with the broader research literature, including demonstrations at C&I facilities and studies in UK/Europe. Finally, lessons learned are shared from the process of converting GTI’s industrial laboratory spaces to improve hydrogen safety for higher-throughput testing with H2. 

Paul GlanvilleSr. R&D DirectorGTI Energy

Introduction; Hydrogen as an energy carrier. Ultrasonic flowmeters for custody transfer measurement have been developed and  tested mainly for measurement of natural gas. With the energy transition, hydrogen is gaining momentum as an energy carrier to complement or replace natural gas. Consequently, there is a need to test the suitability of ultrasonic flowmeters for this gas. As hydrogen has different properties than natural gas (e.g. density and speed of sound) the behaviour of acoustic signals in the gas is different, which may affect the operation and performance of the ultrasonic flowmeter when applied to hydrogen. Therefore, there is a demand for testing of flowmeters on hydrogen. Currently however, there is a lack of large scale flow laboratories for hydrogen and that is why we have agreed to test ultrasonic flowmeters in existing pipelines transporting  pure hydrogen. 

Craig SartisonTechnical Sales RepresentativeGS Hitech Controls

Technical conference delegates can enjoy coffee and refreshments in the delegates lounge along with visiting exhibitors and sponsors on the exhibition floor.

Objectives/Scope: The expanding hydrogen industry requires a credible approach to Process Safety Management (PSM), especially as this energy source is integrated into everyday public use. PSM, with its foundation in the chemical and oil & gas sectors, has a history of valuable lessons learned. The Inherently Safer Design (ISD) methodology is an established tool from the AI ChE Center for Process Safety that can be applied to designing hydrogen systems, offering a robust process design that reduces reliance on less reliable process safety protection layers such as Emergency Response.  Methods, Procedures, Process: This presentation leverages Inherently Safer Design techniques and Layers of Protection from the US AIChE Center for Chemical Process Safety.Results, Observations, Conclusions: Integrating Process Safety during the engineering design phase of a project is crucial. Embedding safety principles early results in more robust, inherently safer processes that are easier to trust, accept, and use. The continuous advancement of Process Safety should transcend proprietary boundaries.Novel/Additive Information: Due to the unique characteristics and hazards of hydrogen, this presentation will provide concrete examples of Inherently Safer Designs within the five ISD categories: Minimize, Intensify, Substitute, Moderate, and Simplify. These examples aim to provoke thought and encourage the application of ISD techniques across the growing hydrogen industry.

Cloribel Santiago FloresProcess EngineerBantrel Co.

Shantanu PatwardhanProcess Study ManagerBechtel Energy Technologies & Solutions, Inc.

Increasing interest, investment and development of the Canadian Hydrogen Economy includes new methods and sources for hydrogen generation, transport and storage; with Underground Hydrogen Storage (UHS) in salt caverns and geological reservoirs being a viable option for short term hydrogen storage. Similar to Carbon Capture Utilization and Storage (CCUS), the development of safe, reliable and robust monitoring programs will be required to ensure storage integrity, provide assurance to stakeholders that hydrogen storage is not resulting in negative environmental impacts, and to facilitate policy development and regulation.A case study of the Fort Saskatchewan area in east central Alberta has been chosen to develop a conceptual model of salt caverns, and their surroundings, based upon regional and local-scale stratigraphy, hydrostratigraphy, and well penetrations. This area already contains multiple storage caverns within the Lohtsberg Salts and is a primary target for future commercial hydrogen storage activities. A Geographic Information System (GIS)-based model is being used to collate existing study area information. Along with empirical laboratory data related to hydrogen diffusion rates through geological porous media, potential hydrogen migration pathways are being prioritized. A comparison of potential hydrogen leakage pathways, both natural and well penetration-related, is being used to develop options for assurance monitoring approaches. Learnings from this study will support assurance monitoring planning, the choice of appropriate hydrogen sensors, and will feed into existing Hydrogen Codes and Standards; with useful information for future industry hydrogen storage proponents.Brydie, J. R.1, Utting, N1., Joy, E.1., Vaislblat, N2, Deblonde, C.3, Brunton, F.4, Carson, R.5 and Gnanapragasam, N.5 1.Natural Resources Canada, CanmetENERGY Devon, 1 Oil Patch Drive, Devon, Alberta. T9G 1A82.Natural Resources Canada, CanmetENERGY Ottawa, 1 Haanel Dr, Nepean, Ontario, K1A 1M13.Geological Survey of Canada, 3303 33 St NW, Calgary, Alberta, T2L 2A74.Ontario Geological Survey, Ministry of Mines, 933 Ramsey Lake Rd., Sudbury, ON P3E 6B55. Canadian Nuclear Laboratories, Hydrogen Technologies Branch, Chalk River, Ontario, K0J 1J0

Nicholas UttingResearch Scientist (Geochemist)CanmetENERGY, Natural Resources Canada

With the rise of hydrogen vehicle pilot projects among commercial and public truck and bus fleets, fleet operators face the challenge of specifying refueling systems that align with both initial vehicle rollout plans and anticipated fleet growth. Refueling rate is a dynamic and complex function influenced by factors such as the refueling system’s storage capacity and state of charge, station compression throughput, vehicle fuel system characteristics, vehicle arrival profiles and variability, and fueling protocol choice. Traditional kilogram-per-day metrics often fall short in capturing the nuances of peak demand and system recovery requirements. This session will examine these critical considerations and present a novel approach to system-level simulation, modeling full-day, dynamic refueling scenarios and storage usage/replenishment. Attendees will be guided through sample scenarios to highlight practical applications of this modeling approach in optimizing for refueling system size, performance, and cost. This modeling approach not only addresses immediate operational needs but also offers a scalable framework to support the expansion of hydrogen refueling infrastructure as fleet demand grows.

Angela DasChief Technology OfficerHyfluence Systems Corp.

Low cost, low carbon intensity hydrogen production is needed to decarbonize a range of existing and new applications such as; steelmaking, heavy duty transportation, and power. Aurora Hydrogen’s innovative microwave-driven methane pyrolysis process produces hydrogen at the point of end use avoiding costly hydrogen storage and distribution. This process also produces minimal direct CO2 emissions. Aurora Hydrogen has built a demonstration scale (200 kg-H2/day) facility north of Edmonton in Fort Saskatchewan to prove the technology, while commercial scale products are expected rapidly upon completion of the demonstration, helping enable demand.

Murray ThomsonCo-Founder and Chief Science Officer (CSO)Aurora Hydrogen

The growing demand for clean hydrogen as a fuel source for zero-emission vehicles and other applications has led to the development of innovative purification technologies. Quantum Technology Corp (QTC) has designed and built a cutting-edge Ammonia Hydrogen Purification Pilot Plant, which extracts and purifies hydrogen from ammonia decomposition at a pilot scale. This innovative system addresses the critical need for ultra-pure hydrogen, especially for fuel cell applications where high purity is essential. Ammonia, with its high hydrogen density, is an attractive hydrogen carrier, but its decomposition into hydrogen poses significant purification challenges. QTC developed a pilot plant demonstrating an efficient solution to this problem. The ammonia decomposition process yields up to 90% conversion rate. Through advanced purification technologies, the system produces ultra-pure hydrogen at greater than 99.999 mol% purity, with ammonia content lower than 10 ppb—exceeding industry standards set by SAE J2719, which permits up to 100 ppb of NH3 and 300 ppm of N2. This system’s performance aligns with our customer’s stringent target specifications of less than 10 ppm N2 and less than 10 ppb NH3. The pilot plant is equipped with a fully automated control system and integrated safety features to ensure reliable operation, making it an ideal prototype for scaling to larger applications. By existing industry standards for purity, The QTC pilot plant exceeds industry standards and provides a cleaner, more efficient hydrogen source for fuel cell vehicles and other critical applications. This presentation will showcase the technical details, performance metrics, and future scaling potential of the QTC Ammonia Hydrogen Purification Pilot Plant. We will also discuss the broader implications for hydrogen production and its role in the transition to sustainable, zero-emission energy solutions. Join us to explore how this innovative pilot plant can pave the way for scalable, ultra-pure hydrogen production from ammonia, a key development in the clean energy landscape.

Calvin WinterPresident Quantum Technology Corp.

The path to sustainable transportation depends on the availability of a strong hydrogen refueling network that can meet growing demands from both commercial and individual users. This presentation will address key aspects of hydrogen infrastructure development, including transportation integration, technological advancements, innovative delivery methods, and high-flow fueling solutions. Together, these elements are critical to the advancement and adoption of hydrogen refueling technology. The reliability of the hydrogen network – particularly consistent fuel availability – is crucial to its success. However, there are practical challenges associated with hydrogen delivery to stations, particularly in areas with limited hydrogen production facilities. To bridge this gap, companies are turning to rolling pipelines – tube trailers that provide a flexible, continuous hydrogen supply to meet local demands without the need for extensive permanent, fixed infrastructure. In addition, advancements in storage, pressure piping components, and refueling equipment help to drive the efficiency, safety, and reliability necessary for the adoption and scaling of hydrogen infrastructure. High flow fueling stations allow for rapid refueling of heavy-duty vehicles, reducing refueling times and ensuring that hydrogen will be the fuel of choice for commercial transportation. Together, these developments are laying the foundation for a resilient, accessible hydrogen refueling network, essential to creating a cleaner and more sustainable transportation ecosystem for future generations.

Pierre PoulainPresident and CEOPowertech Labs Inc.

In 2023 SRC and the Transition Accelerator released a report exploring the potential for Saskatchewan’s Regina-Moose Jaw Industrial Corridor (RMJIC) to produce, use, and export low-GHG hydrogen, thereby reducing emissions and contributing to the economy of the province.  Hydrogen hub networks support reduced emissions and drive market demand by aligning producers, consumers and existing infrastructure for sustainable economic growth of low-carbon hydrogen. The identification of supply-and-demand synergies that exist within those concentrated areas of activity, such as the RMJIC, is key to a strong business case for hydrogen. The hub model also supports the sharing of capital costs for new infrastructure and connections to R&D in commercial hydrogen technology and workforce capacity. A ‘hydrogen hub’ in the RMJIC could build on the existing facilities that currently produce and use hydrogen, as well as the proven CO2 storage in the region, the wind and solar potential of southern Saskatchewan, and the province’s vast uranium resource. All of these assets point to the potential for the RMJIC to produce low-cost, low-GHG hydrogen as an energy carrier and industrial feedstock for domestic and export markets. The study looked at hydrogen demand in the Industrial, Transportation, Commercial, and Residential sectors. The report also covered hydrogen price targets, the geological storage potential for hydrogen, and Saskatchewan-specific challenges, including regional economics, infrastructure, hydrogen supply and government incentives. The presentation will touch briefly on each of the topics covered in the report and conclude with direction on developing a shared vision for the future of hydrogen hub development. 

Erica EmerySenior Research EngineerSaskatchewan Research Council (SRC)

Methane Pyrolysis offers a promising pathway for producing low emissions hydrogen by breaking down methane into hydrogen gas and solid carbon. This paper outlines Ekona’s journey of developing its methane pyrolysis technology, progressing from initial conceptualization to achieving a maturity suitable for industrial demonstration and commercial scaling. At the heart of Ekona’s methane pyrolysis solution lies the xCaliberTM reactor that is based on a constant volume, combustion-driven process. The reactor is non-catalytic, low-cost and mitigates carbon fouling issues that plague other methane pyrolysis platforms. Ekona’s solution produces two co-products, clean hydrogen and solid carbon, that can serve to decarbonize and drive value in numerous industries. Since Ekona’s solution is not reliant on carbon capture and sequestration infrastructure, clean electricity or water feedstock, it can be flexibly deployed wherever natural gas infrastructure exists.In 2023, Ekona completed the design, build and test of 200kg-H2/day brassboard system, which incorporates a pilot-scale methane pyrolysis reactor and key balance of plant equipment. Testing is ongoing and a second-generation reactor is currently under development. Ekona is also presently expanding its Burnaby test facility for complete process integration. Integration testing will be conducted in 2025. Finally, Ekona is actively deploying its first field system. Ekona Gold Creek is a 1 tpd-H2 Customer Demonstration Plant, which will be located near Grande Prairie. Alberta. Construction and commissioning will be completed in 2025, with testing and operations planned for 2026-2027. Ekona Gold Creek will inform subsequent early commercial deployment programs with Ekona’s partners, with FEED programs commencing in 2025 and first commercial installations starting in 2027-2028. Ekona's technology development has been driven by a dedicated team of engineers and scientists. To date, Ekona has secured 37 patents for its innovative solution, reflecting the uniqueness of its technological approach. Throughout the development process, Ekona has consistently improved hydrogen yields, with each iteration of reactor design achieving higher efficiencies. Concurrently, the production of solid carbon has seen significant improvements, with increased yields and carbon purity through successive reactor configurations. Ekona’s solid carbon product resembles commercial carbon black, and the team is working to establish commercial supply chains for that important co-product. The development journey has been supported by valued public and private investment partners. Funding from these sources have enabled extensive pilot testing and continues to support scale-up efforts. Collaborative initiatives with academic and research institutions further enhanced the technology's technical capabilities, ensuring a robust path to commercialization. Ekona’s methane pyrolysis technology offers a scalable solution for clean hydrogen production. The technology's progress underscores its potential to transform hydrogen markets, providing an efficient, low-emissions alternative to conventional production methods. Ekona’s ongoing efforts focus on securing partnerships for commercial deployment and further refining the process for widespread market adoption.

Gary SchubakVP Business Development & Government RelationsEkona Power Inc.

The use of Hydrogen for decarbonization is creating a network of production, transportation and hydrogen consumers. The exchange of Hydrogen between these parties constitutes a custody transfer point, which requires accurate metering of the volumes, as well as ensuring contractual specifications for Hydrogen are met. This metering occurs at various points, depending on the network involved, and requires the use of flow metering technologies to determine the total volumes of Hydrogen transferred. To determine standardized volume, the use of an appropriate flow computer technology is also required. Finally, several standards exist for the use of Hydrogen, requiring different levels of purity that must be analyzed as part of the custody transfer arrangement. Understanding the different technologies available for metering and measurement of Hydrogen is key to selecting the correct instrumentation for custody transfer. This presentation will discuss several technologies and requirements used in Hydrogen Custody Transfer.

Don FordMeasurement Technical Sales SpecialistSpartan Controls Ltd.

Canadian Standards Association, operating as CSA Group (“CSA”), is a not-for-profit membership-based organization accredited by the Standards Council of Canada (SCC) in Canada and the American National Standards Institute (ANSI) in the U.S., serving business, industry, government, and consumers in. The mission of CSA Group’s Standard organization is to enhance the lives of Canadians through the advancement of standards in the public and private sectors. We are a leader in standards research, development, education, and advocacy. In support of Canada’s goal of reducing greenhouse gas emissions, demand for hydrogen and natural gas blended with hydrogen has emerged. These fuels must be delivered and stored in a safe and effective manner. Addressing hydrogen in standards is currently a focus area around the world with support from many international research organizations, industry parties, and levels of governments. As Canada’s oil and gas sector repurposes and develops purpose-built infrastructure for hydrogen delivery and storage, there is a need to update the relevant standards. Recognizing the breadth of potential hydrogen applications, the entire suite of CSA Group oil and gas standards have been reviewed to assess the impacts of hydrogen. This presentation will outline impacted topics for pipeline delivery and large-scale storage of hydrogen and hydrogen blends and summarize the related standards research and updates. Specifically, this includes: • CSA Z662, Oil and Gas Pipeline Systems - The standard formally introduced hydrogen and hydrogen blends in the 2023 edition, and the committee is developing a detailed set of provisions for the 2027 edition. Related research papers addressing materials, components and equipment, and coatings and liners for hydrogen service pipelines. • CSA Z341, Storage of Hydrocarbons in Underground Formations - A supplement to the standard, addressing application to hydrogen and hydrogen blends, was published. • CSA Z625, Well Design for Petroleum and Natural Gas Industry Systems - To support the storage of hydrogen, CSA Z625 was amended to address hydrogen and other gases. Finally, ongoing CSA activities will be described, including continued research needs to support the development of hydrogen related requirements such as Hydrogen Leakage Measurement, Monitoring and Verification.

Mervah KhanProgram Manager, Petroleum and Natural GasCSA Group

Brett WeinkaufProject ManagerCanadian Standards Association

Over the past year and a half, the Alberta government has been exploring several paths to transitioning its government vehicle fleet to hydrogen power. This presentation walks through how we approached collaboration, learning and addressing key conditions needed for such a transition to be viable. Through engaging the investor community, test drive and pilot projects, internal outreach, and research, the Alberta government has worked to advance the goals of Alberta’s Hydrogen Roadmap through the government fleet, which supports hundreds of programs and services. We will be discussing the challenges of transitioning such a public-sector fleet, the necessary journey of learning, discovering the art of the possible, and the importance of incremental successes along the way. The presentation will also cover how our Vehicle Fleet Strategy supports Alberta’s Hydrogen Roadmap, the conditions we've identified for success, making the case for fleet managers using a user-centric approach and test drives, the need for knowledge and incremental progress, and engaging the marketplace and building alliances. The presentation will wrap up with a summary of what we learned so far, and why it mattered.

Frank BuckreusDirector, Strategic Initiatives and Service ExcellenceGovernment of Alberta

B&W has developed a chemical looping technology that can directly process a wide range of feedstock, including solid fuels such as biomass, municipal waste or coal, into hydrogen and separated streams of carbon dioxide (CO2) and oxygen-depleted exhaust (primarily nitrogen). An innovative oxygen-carrying metal oxide particle is used in the chemical looping process. The isolated CO2 can be captured and sequestered or transported for beneficial use, while the oxygen-depleted exhaust can also be captured for use or discharged to the atmosphere. The presentation will provide a short overview of the technology, including current market drivers and financial incentives related to the carbon intensity of the produced fuel. Status updates for two current projects will be presented.

Adam RobinsonDirector, ClimateBright™, Canada, Alaska, and NW statesBabcock & Wilcox

Technical conference delegates can enjoy a hot lunch buffet in the dedicated technical delegate lounge, with lunch included as part of the technical conference pass. Afterward, delegates are encouraged to visit the exhibitors and sponsors on the exhibition floor.

As part of the Hydrogen Strategy for Canada conducted by the Government of Canada in 2020, one of the key recommendations made for positioning Canada as a global hydrogen leader was to support the development of innovative hydrogen technologies. Currently, Canadian companies developing flowmeters, drag reducing agents, and other products for application in hydrogen pipelines must go international for pipeline testing services that validate and qualify their technologies for market use. In 2024, InnoTech Alberta conducted a global market scan to review existing hydrogen pipeline test systems and a gap analysis to identify market capability of hydrogen pipeline testing systems.The global market scan focused on identifying existing hydrogen pipeline test systems that currently serve industry clients and collecting information for evaluating system design, optimizing operating conditions, and addressing common challenges. These systems and their operators are primarily based in Europe or the United States. Work in Europe has focused on flowmeter qualification and large scale material testing, while work in the United States has focused on hydrogen blend testing, pulsation analysis, system dynamic analysis, blowdown system capacity, valve testing, in-situ welding repair and leak detection technology testing. Existing systems can run gas blends up to 100% hydrogen at ambient temperatures, flow rates up to 6,500 Sm3/h, and pressures up to 51 bar(a). Pipeline diameters in existing test systems range from 1 to 12 inches. The gap analysis identified several unique technical challenges and opportunities for new hydrogen pipeline testing capacity, such as transportation efficiency, repurposing of existing pipelines for hydrogen service, blending hydrogen into natural gas pipelines, pipeline operations including injections and purging, metering and hydrogen product delivery. Within Canada, there is an opportunity to develop pipeline testing capabilities for studying topics related to gas flow behaviour such as gas mixing technologies, flow characteristics of different gas blends, and performance of odorants and safety equipment. This presentation summarizes the findings of the market scan, including insights into existing hydrogen pipeline test systems and potential new scopes for hydrogen pipeline testing. The dialogue generated by potential end users in response to this presentation will feed into developing a successful hydrogen pipeline testing system at InnoTech Alberta that both aligns with and serves the Albertan and Canadian hydrogen markets to close some of the industry gaps identified. Ultimately, this will help technology developers, project proponents, and regulators across the midstream and downstream transportation sectors to safely, sustainably, and reliably design, implement, and operate hydrogen pipelines and equipment.

Kira WongResearcherInnoTech Alberta

H2 plants supplied by renewable energy have to adapt their production depending on the renewable energy availability. Varying renewable power generation requires varying load situations of H2 plant. Poor control of input voltage for an electrolyser plant causes more losses, higher harmonic emissions and require more reactive power compensation. A combination of well-designed harmonic filter and reactive power compensation systems (hereafter power quality solution) interacting with an intelligent on-load-tap-changer (OLTC), makes the usage of thyristor technology for H2 plants highly cost efficient and increases overall electrolyser efficiency and lifespan. Such a coordination between power quality solution and OLTC can only be defined based on intensive network simulation analysis. Hence, such a simulation analysis shall be carried out during an early stage of project planning and design finalization of H2 electrolyser plant. This paper focuses on how an accurately designed power quality solution in conjunction with suitable OLTC tap positions facilitates in reduction of not only overall capital expenditure by significantly reducing the power quality system requirements but also reduces operational expenditure during changing requirements within H2 cells lifetime (which is begin of life and end of life operation). 

Jarrod MajethRegional Sales ManagerMaschinenfabrik Reinhausen GmbH

Objectives/Scope: Low-carbon hydrogen integration into Canada's energy systems is critical to achieving the country's ambitious climate goals. As the global demand for cleaner energy solutions rises, hydrogen stands out as an option that can decarbonize various sectors, including industrial, agriculture, residential and commercial energy systems. Canada, with its abundant natural resources and advanced energy infrastructure, is well-positioned to lead this transition. The objective of this research is to develop a comprehensive framework for integrating low-carbon hydrogen into multi-regional natural gas energy systems through hydrogen-natural gas blending. This study aims to reduce the carbon intensity of energy use across residential, commercial, industrial, and agricultural sectors, facilitating the transition towards a net-zero emissions economy. Specifically, the framework will identify hydrogen production, transmission, and trade opportunities between regions, applying a 20% hydrogen blending strategy into existing natural gas infrastructure. Additionally, this study includes analyzing the greenhouse gas reduction potential and economic impacts of blending low-carbon hydrogen. Methods: Three distinct low-carbon hydrogen trade regimes were developed to analyze hydrogen production and transmission across Canadian provinces. A set of 528 long-term scenarios were modeled for large-scale integration of low-carbon hydrogen into Canada's natural gas energy systems, addressing hydrogen supply across all sectors. These scenarios were considered varying hydrogen production technologies, trade regimes, and carbon policies across regions and sectors analyzed through a robust bottom-up systems approach. The impacts on greenhouse gas (GHG) emissions and energy system costs were calculated and compared for all the scenarios, providing critical insights into the potential for decarbonization and economic implications. Results Conclusions: This study develops a multi-regional framework and identifies ATR-CCS as cost-effective for hydrogen production in natural gas-rich regions like Alberta and British Columbia, while grid electrolysis is suited to areas with low-emission electricity, such as British Columbia, Ontario, Quebec and Manitoba. Alberta exporting low-carbon hydrogen produced through ATR-CCS to other provinces and British Columbia producing its own hydrogen offer the lowest hydrogen prices for every region, and also, depicts the lowest marginal abatement cost of 40 CAD/t at a carbon price of 350 CAD/t CO2e. Grid electrolysis scenarios with British Columbia, Manitoba, Ontario and Quebec as producers provide the highest GHG reductions, i.e., 4.6% at a carbon price of 350 CAD/t CO2e from 2026 to 2050. Novel/Additive Information: Current research focuses on the blending of hydrogen and natural gas in transmission pipelines; however, inter-regional low-carbon hydrogen trade and its effect on the GHG reduction potential of blending with natural gas requires further examination. These gaps highlight the need for further research to examine the challenges and opportunities associated with developing the hydrogen economy, especially from two specific lenses – a multi-regional jurisdiction with diverse energy characteristics and an economy-wide scope with full energy system representation.

Shibani .MSc StudentUniversity of Alberta

There is a significant driver to achieve high carbon capture rates for new and existing plants. This approach is environmentally driven, and the intention is to minimize the impact of new plant, which produce NH3 based on fossil feedstock, e.g. natural gas. Many projects target extremely high capture rates and some of these advertised approaches are going beyond 99%.There is no doubt, that extremely high capture rates can be achieved with available technology already today. However, to focus on the capture rate only seems is a limited perspective. It turns out, that the focus is for many suggested projects strongly on the plant itself and misses other important items related to the very high carbon capture rates. It is clear, that the higher the target capture is, the higher the more the design needs to focus on this task. Above certain Carbon capture rates more catalyst need, more compression, more equipment, etc. are required which can fail and impact the reliability of the ammonia production. The presentation will explain by a study for a world-scale ammonia production that there is a sweet spot for the good level of carbon capture rate. However, such a sweet spot is not only defined by the plant’s carbon capture rate, which covers the direct emissions only. Capital investment, plant availability, plant energy efficiency, constructability, and OSBL impacts are having an important influence on the reasonable carbon capture rate. It turns out, that even the used technology approach can support the decision for a specific site. Due to that, flexibility of the selected unit operations as well as a good choice of the proposed plant operating conditions help to fine tune the best approach and the best economical approach achieving the product with the lowest carbon footprint.

Thilo von TrothaBusiness Development DirectorLinde

Objectives/Scope: DNV, in collaboration with National Gas, has replicated the gas transmission network at DNV's cutting-edge Research and Testing Laboratory in Cumbria, UK. The project aimed to determine if National Gas Transmission (NGT) assets could effectively operate on hydrogen blends as well as 100% hydrogen.The presentation/poster will provide an overview of:1. The nature of the project2. Its objectives3. Achievements obtained4. Future stepsMethods, Procedures, Process: The project's objective was to perform hydrogen testing on repurposed National Gas assets that had been operational on the National Transmission System (NTS). This included components like valves, meters, gas quality equipment, and pre-heating systems. The testing programme comprised of hydrogen concentrations of 2%, 5%, 20%, and 100%.Throughout the test programme, leakage, noise, vibration, and operability of the assets were measured.Results, Observations, Conclusions: • All assets performed as expected compared to natural gas during the testing programme.• No notable increase in noise was recorded during venting, except for the 100% hydrogen test, though there was no rise in vibration levels.• No permeation through pipe walls was detected.• Temperature change measurements through pressure reduction validated the models and indicated no need for pre-heating with 100% hydrogen.Novel/Additive Information: Full-scale testing to demonstrate the suitability of existing natural gas transmission assets with hydrogen would not be feasible without this facility. The project has shown that many NTS assets can be adapted for 100% hydrogen use with minimal modifications. The insights gained from this project are applicable to international transmission operators and can aid these organisations in exploring their own hydrogen transmission pipeline development.The findings from this project are instrumental in shaping the development of the hydrogen backbone in the UK.

Adam MadgettPrincipal Hydrogen ConsultantDNV

As companies start to build out infrastructure for hydrogen, they tend to go back to follow an old play book. Hydrogen is an extremely small molecule and needs thoughtful choice of components in order to safely handle and control its many challenges. Some of those challenges include, wide flammability range, difficulty for sealing in valves and fittings, cleanliness requirements and behavior of a non-ideal gas. With an exciting future in the industry, we offer a discussion of owner companies taking ownership in the types of components that are specified by their EPC firms and eventually package vendors. Going with the lowest bidder is not always the most economical solution. We offer some strategies to ensure quality components, assemblies and installations that can be properly maintained into the future. These include: owner companies specifying the requirement for single suppliers of high quality components for all fittings and valves, regardless of integrator for sub systems requiring proper training for all installations understanding and specifying proper materials of constriction.

Chuck HayesGlobal Technical Lead Clean EnergySwagelok

Objectives/Scope:We aim to highlight how hydrogen heating can grow from a single home to an entire community, positioning Alberta as a global leader in this field. This presentation shares the story from HomeOne's prototype stage to Bremner’s planned community scale, with insights into the economic potential, technological advancements, and practical applications of hydrogen in residential energy. The presentation will also highlight and provide insights into proprietary technology being pioneered right here in Alberta through the development of a conversion kit for natural gas furnaces to be fueled by hydrogen.  Methods, Procedures, Process:This session will combine technical details with insights from ATCO, Qualico, and Gradient Thermal, and will highlight each partner’s role in the Home Hydrogen continuum. Attendees will follow the journey from the HomeOne pilot to Bremner’s community-wide vision. Through a mix of data, project highlights, and partner perspectives, we’ll cover the collaborative efforts, technical challenges, and community benefits that make this approach to residential heating possible.Results, Observations, Conclusions:The HomeOne pilot has shown that hydrogen heating works effectively even in Alberta’s harsh winters, proving itself as a viable alternative to natural gas. We’ve found that hydrogen heating isn’t just safe—it also supports Alberta’s long-term goals for emissions reduction, job creation and economic diversification. This success lays the groundwork for hydrogen heating on a larger scale, positioning Alberta as a leader in the hydrogen economy.Novel/Additive Information:The Bremner project represents a new level of possibility for hydrogen as a heating source, demonstrating how entire communities can adopt this sustainable energy solution. This project is not just a milestone in reducing emissions; it’s also a powerful economic driver, creating jobs and attracting investment. This presentation will share unique insights into the technical, community, and operational aspects of making hydrogen heating work in real-world settings, offering a forward-thinking model for sustainable living.

Brad ArmstrongRegional Vice President of Northern AlbertaQualico Communities

The most significant and urgent barrier to the rapid adoption of clean hydrogen, is its production, at scale, without significant carbon dioxide emissions and at a price that is competitive with fossil fuels. Although green hydrogen (via electrolysis) is a relatively mature approach, its cost projections are not very encouraging in the near and medium term. Similarly, whilst steam methane reforming is widespread, adding carbon capture is costly and necessitates a parallel buildout of CO2 infrastructure. Moreover, centralized hydrogen production requires new distribution infrastructure creating additional delay and cost. Thus, it is not hyperbole to state that the future of the hydrogen economy rests on our ability to find alternative production methods for low-carbon hydrogen that is scalable and cost-competitive. Moreover, there would be an added value attached to a production method that can be distributed – that is, positioned near large sources of demand so as to limit the need for delivery infrastructure. A scalable, decentralized production method therefore not only helps make hydrogen cost-competitive, but also creates an opportunity for more rapid deployment. With these challenges in mind, there is growing interest in the pyrolysis of bio-methane or natural gas to produce clean hydrogen since it has the potential to address many of these barriers. First, since it creates easily separable solid carbon, this can be stored and transported without additional infrastructure. This not only makes the production method carbon-neutral (or carbon negative in the case of bio-methane) but also presents a source of revenue, thus potentially lowering the cost of hydrogen. Secondly, the pyrolysis approach presented in this paper is highly scalable creating on opportunity to utilize our current gas grid as the distribution network and generating hydrogen at grid-edge according to demand. The objective of the presentation is to introduce a unique approach to methane pyrolysis for hydrogen production. The New Wave pyrolysis system has, at its core, a unique shock-driven heating technology that makes carbon separation and handling much more efficient compared to competing approaches. The analysis will use a combination of detailed CFD analysis of key components as well as a comprehensive system model, i.e., a plant design for the production of hydrogen and carbon. The aim is to develop a system configuration that includes heat and driver gas recycling such that the balance between hydrogen conversion and energy input is optimized. Thus, the presentation will show the results from this detailed system modelling and predict the energy required to produce a kilogram of hydrogen. The system also uses a novel two-step reaction system that initiates the reaction thermally in the absence of a catalyst, but prolongs this reaction in a self-seeded, carbon-catalyst reactor design. This is described and contrasted with other approaches.

Colin CopelandAssociate ProfessorSimon Fraser University

Technical conference delegates can enjoy coffee and refreshments in the delegates lounge along with visiting exhibitors and sponsors on the exhibition floor.

As part of the emission reduction efforts, Enbridge Gas, a leader in North American hydrogen initiatives, is evaluating the Enbridge Gaz Quebec network in Gatineau, QC for hydrogen blending with natural gas. Amongst other assets, the network includes valves, flanges, fittings, and other components made from cast materials. Relevant codes and standards such as ASME B31.12 and AIGA 087 do not permit their use, while IGC 121 allows it under low-stress conditions. CSA Z662 could permit for the use of cast iron components if an engineering assessment is completed. However, there is limited literature and published data on the hydrogen compatibility of cast materials. Given that cast iron fittings were installed widely across the network, replacement is not a practical option. As a result, Enbridge Gas conducted a project with C-FER Technologies to evaluate the performance of cast materials in a hydrogen environment. The study explores the effect of hydrogen on ductile iron, malleable iron, and gray iron in designed to ASME B16.3, B16.1, ASTM A197/A197M, and A126. The objective of this project is achieved by characterizing the materials in order to allow for a risk-based evaluation on the impact of the addition of hydrogen to the network. The project is divided into several phases due to its breadth of scope. The initial phase of the project is focused on information gathering related to publicly available material testing information, EGI network information, and supplemented by a material testing program conducted at C-FER. 

Daniel FujinagaResearch EngineerC-FER Technologies

Tahrim AlamSenior EngineerEnbridge Gas

The Hydrogen Strategy for Canada has identified the harmonization of hydrogen codes and standards, along with addressing existing gaps, as essential steps for enabling the adoption and deployment of low-carbon hydrogen. Gaps in codes and standards present significant obstacles to the widespread production, delivery, storage, and end-use of clean hydrogen. To address these challenges and establish a strong foundation for hydrogen deployment across Canada, Natural Resources Canada (NRCan), in partnership with the Standards Council of Canada (SCC), has released the first Canadian Hydrogen Codes and Standards Roadmap.Developed through the Codes and Standards Working Group with broad stakeholder participation—including governments, industry associations, businesses, regulatory authorities, end-users, and accredited standards development organizations—this Roadmap systematically identifies critical gaps across the hydrogen value chain within the Canadian context. The working group defined the hydrogen value chain (production, delivery and storage, and end-use), conducted a gap analysis, identified potential actions to address standardization gaps, and implemented a rating system to classify and prioritize these gaps into short-, medium-, and long-term categories. Key priorities stemming from the Roadmap include but are not limited to carbon intensity determination, gaseous hydrogen storage, injection into pipelines, and hydrogen use in transportation and industry. Additionally, recommended actions for the Canadian hydrogen sector focus on governance, policy measures and regulatory action, international cooperation, innovation and capacity building, information technology and access, and communication and harmonization. To support future standardization efforts, the National Research Council has developed the Hydrogen Codes, Standards & Regulations Mapping Website as an online complementary resource.

Jillian TownsendEngineerNatural Resources Canada (NRCan)

This presentation will highlight the most up-to-date North American and International Regulatory Code requirements and Industrial Standards for Hydrogen Safety. The presentation will focus on hydrogen gas leak detection and response requirements in Safety Systems for all Hydrogen Technologies in Production, Usage, Transport, and Storage for applications including, but not limited to; electrolyzers, hydrogenation processes, H2 fuel cells and vehicle re-fueling stations. The introduction begins with a summary of the significance and severity of gas leak hazards and the reported Lost Time Incidents related to Hydrogen gas leak events and explosions. The presentation defines the differences between Regulatory Codes and Industrial Standards versus Best Practices and User Guidelines for gas, fire, and flame detection. Consequences for decisions made to follow or not follow each type of design criteria will be discussed. The main purpose of the presentation is to inform about key updates over the past 2-3 years to the Codes & Standards that when implemented properly, can improve the plant’s operating conditions through enhanced safety system design at the earliest stages of a facility’s construction. Among others, the presentation identifies and defines where, along the Hydrogen value chain, the many different Codes and Standards would apply in the design of Safety Systems for those facilities. Some of those Codes & Standards to be referenced include the National Fire Code of Canada:2020, NFPA 55:2023, NFPA 2:2023 for Hydrogen Technologies, NFPA 853:2020 and NFPA 72:2022, the International Fire Code (2024), the applicable clauses of ISA 84, the Industrial Standard for Process Control & Process Safety, and the applicable ISO Standards. Finally, the presentation offers a route to compliance for the end user that provides code-compliant engineering documentation to support their Hydrogen Safety System designs.

Jean BertholdStaff Applications EngineerDraeger

In our work, we set out to elucidate the light-harvesting properties of various random and ordered photocatalyst supports (PSs) with different macropore sizes, and random, ordered and graded arrangements. To accomplish this, we propose two studies of increasing relevance, enabled by computed tomography (CT) reconstructions and raytracing COMSOL Multiphysics simulations: (a) a 360-degree light release study approximating a PS situated within a compound parabolic concentrator (CPC) or cylindrical LED reactor with open ends; and (b) the same system as before but with closed ends. The ordered geometry is of interest, as it can be 3D printed at scale with a tailored morphology and porosity, and it can potentially be refined using machine learning models to optimize its light-harvesting properties. As will be shown, the local volumetric light absorption (LVLA) data suggests that an ordered PS with a more open pore interior and a smaller pore exterior would begin to approach the more isophotonic light-harvesting properties of random PSs.Building on our investigation of photocatalytic properties, an illustrative example of a potential practical application from our study is the direct photocatalytic conversion of ethane, a hydrogen carrier, to ethylene and hydrogen under ambient conditions. This approach eliminates the need for high temperatures, an energy-intensive process that significantly contributes to greenhouse gas emissions. The highest ethylene production rate and ethane conversion achieved were around 1.1 mmol·g⁻¹·h⁻¹ and 4.9%, respectively. The viability of a solar-driven hydrogen and ethylene production process is further demonstrated by the successful operation of a rooftop prototype system.This research seeks to enable low-temperature photoreforming of hydrogen carriers to reduce the overall energy intensity, gas cleaning requirements, and ultimately cost of delivered hydrogen. The overall goal to increase the photocatalytic efficiency will enable competitive hydrogen costs versus drop in hydrogen carrier use.

Athan TountasPostdoctoral Research FellowUniversity of Toronto

Rui SongPostdocUniversity of Toronto

The transition to clean energy requires both technological innovation and economic viability.This presentation provides a data-driven analysis of the Levelized Cost of Hydrogen (LCOH) based on Accelera by Cummins' experience deploying and operating industrial-scale green hydrogen facilities.Based on several operational electrolyzer installations, we will present a comprehensive LCOH modeling that includes both theoretical projections and real-world performance metrics. The analysis will highlight key cost drivers, including capital expenditures, electricity prices, capacity factors, and operational efficiencies that drive LCOH outcomes in various deployment scenarios.Attendees will gain insight into:Comparative economics between PEM and alkaline electrolyzer technologies Critical sensitivities in LCOH models and their validation in the real world Regional variations in LCOH across different jurisdictions Strategies for optimizing electrolyzer operations to minimize LCOH Practical approaches to balancing intermittent renewables integration with hydrogen productionWe will share case studies that demonstrate how operational experience has refined our LCOH models, identified discrepancies between projected and actual costs, and revealed optimization opportunities that can only be discovered through continuous operation.

Henry MaSales & Business Development Director – Electrolyzer AmericasAccelera by Cummins

ObjectivesA strong hydrogen value chain is necessary to make hydrogen truck adoption economically viable.The core issue is that the components of a new value chain don’t exist at a scale that is economically viable and need to be simultaneously formed: hydrogen production, hydrogen delivery, hydrogen fueling stations, production of trucks, and supporting services such as technicians, service facilities, spare parts, insurance, and training. To approach economic viability, a minimum scale of demand needs to be achieved. Achieving this scale requires investment in hundreds of hydrogen trucks, and a long-term commitment to hydrogen fuel purchases—a risky proposition for trucking companies. There is a need for a framework that describes the minimum viable scale of the value chain and an approach that increases the chances of success. The objective of the Minimum Viable Corridor is to establish such a framework. MethodsA successful hydrogen value chain has two components: risk management and profitability. Every link in the value chain needs low enough risk and high enough profit because a single weak link can break the chain and leave trucks unable to operate. The needs of all stakeholders need addressing—production and delivery of hydrogen, fueling stations, truck manufacturers, service providers and ultimately the end user: trucking companies. The Transition Accelerator has developed a Minimum Viable Corridor framework through extensive techno-economic analysis and deep engagement with stakeholders in the trucking and hydrogen supply sectors. The framework identifies the qualitative risks that need to be managed, and quantitatively calibrates them to a minimum scale that can achieve economic viability. ConclusionsThis greatest chance of success is to focus efforts and investments on building a hydrogen value chain along an existing heavily trafficked commercial freight corridor—A Minimum Viable Corridor.A Minimum Viable Corridor consists of a few fueling stations and a few hundred trucks operating in full commercial service. It is held together by contracts that lock down key components like price and availability of hydrogen, amount of hydrogen consumed, leasing costs for trucks, availability of maintenance and spare parts, truck performance, and so on.The novelty of this approach requires stakeholders to enter long-term multi-lateral agreements. Public funding is needed along side private investment, but the Minimum Viable Corridor framework optimizes investments and maximizes chances of economic success. Modelling shows that the magnitude of public investment to transition the heavy-duty trucking sector is less than the amount of carbon tax that is currently being paid by the sector. And, the investment from trucking companies would be no more than what they are already investing in trucks, fuel, and operations.

Mark Lea-WilsonSenior AdvisorThe Transition Accelerator

Hydrogen is not a one-size-fits-all solution to the energy transition, but it is gaining traction and taking on an increasingly important role as a solution to decarbonize sectors and activities with “hard-to-abate” emissions. Chief among these industries is long haul heavy transportation. This sub-sector is targeted for improvement due to its disproportionately high GHG emissions from large heavy-duty commercial vehicles. Expectations for successful emissions abatement are growing as zero emission hydrogen vehicle technology matures and new trucks from several major OEMs begin to proliferate the market. Objectives/Scope: From a systems thinking perspective, there are layers of unknowns in the current state of the hydrogen transportation ecosystem in Alberta. There are material uncertainties related to vehicle and hydrogen availability and cost, the required maintenance of the trucks, fueling infrastructure development and geographic coverage, and a dynamic policy environment including vehicle incentives, ZEV sales mandates, Clean Fuel Regulations, carbon pricing and credit generation. It is therefore a daunting task to evaluate whether integrating hydrogen vehicles into a fleet is a viable business option. Methods, Procedures, Process: Utilizing AMTA’s member base, we will assess quantitative metrics of adopting hydrogen as a zero-emission trucking solution and integrate a layer of qualitative information (e.g. case studies) to develop an understanding of how, who and when hydrogen adoption should be considered. This will be informed by a quantitative hydrogen readiness score (Hydrogen Fuel Adoption Readiness, HFAR), which is under development and subject to change: HFAR=(Ef×We+If×Wi)×(Tf× Ev×Ni)Where:Ef = External Factor score (0-1)If = Internal Factor score (0-1)We = Weight of External Factors (0-1)Wi = Weight of Internal Factors (0-1)Tf = Technical Feasibility Score (0-1)Ev = Economic Viability Score (0-1)Ni = Environmental Impact Score (0-1)Results, Observations, Conclusions: Using a box and arrow model to represent the hydrogen freight transportation ecosystem, we will attribute value to each metric, extract and explain the most important elements and present actionable strategies that can be used to support building out a business case for zero emission hydrogen truck adoption. This includes understanding projected market pressures to prove sustainability (in operations), emissions quantification and reporting regulations and climate-related disclosures. Further, we will explore leveraging financial incentives, such as clean fuel credits that can be utilized to help offset the upfront capital costs associated with vehicle purchases and ongoing operational costs. Novel/Additive Information: This research moves from the why (benefits/feasibility of hydrogen vehicles) to the how (i.e., building a pragmatic strategy for hydrogen ZEV adoption). The synthesis of technical, financial and policy information presents an evidence-based, practical view of how fleets can move to adopt hydrogen ZEVs in Alberta in a way that makes sense for their business.  

Eric EntzPresidentJoint Advisory Group

In a world that seeks cleaner energy sources, the emerging hydrogen sector remains one Hindenburg Disaster away from losing its social license and the current governmental support it needs for further development. Over the last decade, much progress has been made in relation to the standards that are required for the world to produce, store, transport and distribute hydrogen across the range of differing regulatory regimes and industrial uses. Unfortunately, gaps remain, and differences exist between what is presented as best practice across standards. The objective of this paper is to allow the reader to understand the gaps and differences between standards in greater detail, whilst presenting a reference study for hydrogen project developers to use as they progress from concept to operations. Where standards lack guidance on project distinctions (e.g., novel pipeline configurations or ambitious operating capacity) this paper will outline what reference resources are available and what global project experience can teach the sector, to ensure a safe design is developed.The paper will outline the output from a review and mapping of the current available international and national standards. The mapping will show the reader the gaps in coverage and provide insights in standardization approach used, the degree of prescription of use and will apply objective comparison and scoping criteria to inform what can be offered as best practice approach. Standard metadata will be compiled, including the level of prescription, adoption within each jurisdiction, year of issue and planned revisions, with cross-referencing to other standards where appropriate.

Will SharpeConsulting Manager, Canada Kent

Enbridge Gaz Quebec will be constructing a NPS 10, 20+ km length pipeline to transport fuel-cell-quality gaseous hydrogen from a producer to customers of pure hydrogen and to its natural gas distribution network for blending. While hydrogen pipelines have been designed and constructed in Canada, the majority have been in industrial or process settings. This presentation will discuss the design approach for this pipeline, following requirements of the CSA Z662-23 Oil and gas pipelines standard, and include topics such as material selection, pipeline surface loading and fatigue cracking risk evaluation, inline inspection, leak detection, and route selection.

Laura WongSenior Pipeline EngineerEnbridge Gas

Ivan MykulaSenior Pipeline EngineerStantec Consulting Ltd.

Alberta Motor Transport Association (AMTA) has been interacting with heavy duty hydrogen vehicles since 2022. During 2024 and 2025 five fuel cell electric vehicles (FCEVs) will be operated by AMTA members to support their business operations. Quantitative and qualitative operational vehicle data will be collected during AMTA’s FCEV trial. Baseline data collection will be completed Q4, 2024 in the Edmonton region. A weather station and data acquisition system will be used to collect time stamped data. Data from three defined vehicle speeds, for three measured cargo weights, on flat pavement and on two measured road grades will be collected. Data will also be collected from a diesel tractor for all measured scenarios. Following baseline data collection, similar data collection scenarios will be examined as carriers complete their daily freight deliveries. Real world operational data will be collected through all four seasons. The trial is supported by a variety of available FCEV configurations that include two AZETEC FCEVs, two Nikola Tre FCEVs, and one Hyzon HYD8-200. The AZETEC trucks are demonstration vehicles designed to support Canadian weights and winters. AZETEC is rated for a gross vehicle weight of 140,000 lbs., utilizes compressed hydrogen at 350 bar and has an onboard fuel capacity of 66 kg. The Nikola TRE FCEVs are production vehicles supporting US weights of 82,000 lbs. Nikola requires hydrogen compressed at 700 bar and has an onboard fuel capacity of 70kg. The Hyzon HYD8-200 FCEV is a retrofit vehicle that also supports US weights of 82,000 lbs. Hyzon requires compressed hydrogen at 350 bar and has an onboard capacity of 50 kg. A conventional diesel internal combustion engine vehicle data will also be used throughout the trial as a comparison contrast. Each vehicle trial scenario provides data representing a unique set of operational conditions. This study is being completed to identify the best operational uses cases for FCEV in heavy duty transportation. Numerical and subjective (driver experience) data will be used to inform journey management and current unknowns such as hydrogen cost per kilometer, time to fuel, fueling barriers, and not yet identified operational obstacles. The presentation for the Canadian Hydrogen Convention will include baseline trial data, trend analysis, as well as subjective feedback from the drivers, mechanics, and carriers operating the trial vehicles.

Terri JohnsonManager, Industry AdvancementAlberta Motor Transport Association

Purpose Sustainability practices and environmental well-being have become important in recent years in various industries and maritime transportation is not an exception. This paper aims to explore the intricate relationship between shipping economics, environmental sustainability, and climate considerations in the maritime industry. Through an extensive literature review, it synthesizes insights from various studies, emphasizing the importance of integrating green supply chain management practices. Our problem statement for the research study is, Identify realistic strategies for reducing transportation emissions in the maritime supply chain while ensuring economic sustainability. Design/methodology/approach This paper provides investigation through the factors impacting cost and emissions and proposes a methodology in which an adjustment model is introduced to strike a balance between these criteria. Additionally, the research presents a conceptual model for optimization, aligning economic goals with sustainable practices. This interdisciplinary approach contributes to the discourse on sustainable maritime operations, striving for a harmonious balance between economic growth and environmental responsibility. Findings Key strategies such as speed reduction, green investments, maintenance enhancement planning, emission trading schemes, collaboration with other parties and alternative fuels are examined for their potential in promoting sustainability. The study advocates for collaboration among industry stakeholders, policymakers, and researchers to steer the maritime sector towards a greener future. Originality In order to encourage shipping companies to stay informed about the latest ethical regulations and implement these measurements, there is a collective data and model missing which can be applied to each situation and obtain optimum solution based on their characteristics. Keywords: maritime shipping, green supply chain, emission reduction, shipping fuel cost, shipping time, supply chain optimization model, financial sustainability, ammonia fuel, supply chain decision making, resilience in supply chains, emissions permits, shipping economics

Reza EnalouiResearcherUniversity of Alberta

This presentation assesses the cost of producing and transporting blue and green ammonia from Canada and the U.S. to Europe and Japan. Our analysis covers the costs and availability across the entire value chain, including electricity, carbon sequestration, hydrogen and ammonia production, federal incentives, and transportation. We compare delivered costs to evaluate competitiveness against each other and alternative energy sources. Finally, we examine Europe and Japan’s strategies for securing and utilizing these resources, offering insights into the prospects of North American projects in these markets.

Alex NevokshonoffSenior AssociateEnverus

Technical conference delegates are invited for an evening of networking and entertainment. Access to the Opening Night Reception is included with your technical conference pass. Location to announced.