Hydrogen projects are rapidly developing across Canada and the globe, given the push for low carbon and net zero carbon fuels. While hydrogen regulations and Codes & Standards exist in most jurisdictions, the application of the existing guidance does not always align with engineering guidance or the available products/suppliers. This is primarily being driven by the market, and resulting technologies, moving faster than regulatory bodies and code development can. This can result in two main gaps of concern. The first is that there is a design scenario that is not covered by regulation, and relies on manufacturers, developers, or engineering firms to justify their solution and address the gap on a case-by-case basis. The second is a mis-match in regulations between jurisdictions. While the second is typically addressed by managing to the more stringent set of requirements, both gaps lead to safety considerations as well as commercial and project development constraints. This presentation will provide a review of gaps in current codes and standards, from the lens of project development, identifying areas of overlap and mis-match, and the engineering driven safety in design principles and procedures that can be used to address them.

If the energy transition and deep decarbonisation envisaged by governmental and international policy announcements is to become a reality, hydrogen will have to play an integral role. For this to be economically attractive and technically feasible existing infrastructure, including pipelines, will need to be used. Although the drivers are clear, there is a lack of code guidance about how to technically achieve this while maintaining safety, and only one pipeline in Europe has so far been repurposed by a gas transmission system operator (TSO) under very restrictive operational conditions. This presentation will explore the integrity considerations and challenges associated with successful repurposing and outline how they are being addressed in Europe and elsewhere. An integrity-focused framework will be presented, providing a phased technical approach repurpose pipelines in the energy transition and to manage the introduction of hydrogen into the global pipeline network.

Objectives/Scope: As of June 29, 2021, Canada enacted the Net-Zero Emissions Accountability Act to legislate a net-zero GHG emissions target by 2050. Alberta's power is currently generated with 87% fossil fuel (coal and natural gas) and 13% renewables (mostly wind and biomass), emitting 60% of Canada's power sector emissions. As our economy attempts to reduce greenhouse gas emissions, Alberta's electricity generation must transition significantly to achieve the net-zero target by 2050. This study aims to assess the role that low-carbon hydrogen-based power can play in operating a decarbonized power grid. Methods, Procedures, Process: A rigorous energy systems model of Alberta's power grid is used to conduct simulations and cost-benefit scenario analysis to the year 2050. Scenarios are developed that showcase how hydrogen produced from different Alberta technologies can provide clean firm power through different types of power plants, such as combined cycle power using hydrogen produced from autothermal reforming with carbon capture and storage. Results, Observations, Conclusions: A net-zero power grid will be clean-firm power for a reliable grid. Low-carbon hydrogen can enable a zero-emission power grid by generating energy when renewable energy output is low. The costs of scenarios with different technology mixes are evaluated. Novel/Additive Information: There is no conclusive research investigating the role that low-carbon natural gas-based hydrogen (such as from autothermal reforming with carbon capture and storage) can play in decarbonizing the power sector. This analysis will inform industry and government policymakers about the utility of clean hydrogen-based power so effective decisions and policies can be made.

The world today produces over 90 million tonnes per annum (Mtpa) of hydrogen, almost all from steam methane reforming (SMR) that is as dirty as coal-fired power generation. Electrolysis from renewable energy is much cleaner but also higher cost and consumes huge amounts of fresh water (14-18 t/t H2), making it impractical in solar-rich but water-poor areas. Enhanced Hydrogen Recovery™ (EHR™) technology can produce the “greenest blue” hydrogen with lower carbon intensity than green hydrogen from hydropower and minimal fresh water, at a cost that’s less than half the cost of hydrogen from SMRs. EHR™ produces hydrogen-rich syngas from ultra-deep coal and brine in-situ and re-injects associated CO2 back into the same deep seam for permanent geological sequestration, turning coal ‘from a source to a sink’ of CO2. EHR™ symbiotically integrates proven underground coal gasification with injection of supercritical CO2 to mobilize saline water contained in the coal matrix into the low pressure reaction zone for enhanced hydrogen recovery. The CO2 that comes to the surface is captured and reinjected back into the pore space created by extracting water and gasses from the coal matrix for adsorption on the coal increasing permanence of sequestration. This process all takes place on-site without costly transportation using cogenerated low-carbon, low-cost energy for compression. This syngas is efficiently processed into low-cost, low-carbon hydrogen at surface and can be used directly (heat, power, transportation), or processed further to produce the ‘greenest blue’ ammonia, methanol, and other chemicals critical to decarbonizing difficult industries. EHR™ technology can help decarbonize Canada’s oil and gas industry (e.g., decarbonization of natural gas supplies, bitumen/petroleum upgrading and petrochemicals) and establish a new Alberta Advantage in cost and CO2 emissions. The first EHR™ plant is in development for initial commercial production of 7 t/d of clean hydrogen from stranded hydrocarbons east of Red Deer, Alberta operational by 2024. The initial hydrogen plant will solidify EHR™ claims to be the ‘greenest blue’ hydrogen by having real world realizations of GHG emissions, land use, and water use to pave the way for global scale up. EHR™ provides a way for Canada and others, especially China, India and developing countries, to use their huge coal reserves cleanly.

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.

In a virtuous pursuit to reduce harmful emissions for the people and to tackle climate change, all the recent gas turbines technology developments have been focused on reducing GHG emissions. Since beginning of this century there has been a growing interest in hydrogen as fuel for power generation, transport and domestic use and there has been a tremendous effort increase in the last decade to solve the technical challenges from hydrogen utilization as fuel gas. This paper describes details about the development and optimization of the NovaLT16 package enabling the use of 100% hydrogen as fuel gas in the entire range of applications with relevant challenges, analyzing also all the auxiliary systems to ensure safe and robust operability. The enhancement and optimization of the combustion system (able to operate with fuel gas up to 100% H2, while delivering 15 ppm NOx when operating with natural gas) will be showed, based on the burner technology design criteria, the numerical analyses, and the experimental verifications aimed to improve the design reliability and reduce the development risks. Relevant results of a full annular rig verification test for the full pressure and temperature and full-scale combustion system will be presented, showing the beneficial effect in terms of NOx abatement of a water injection system integrated in the fuel nozzles design and able to operate without jeopardizing the combustion system mean time between maintenance. This paper will describe also specific case studies where the value proposition of these technologies will be highlighted, starting from the powergen application (balancing power in green hydrogen production plants) or mechanical drive services (hydrogen compression for storage or hydrogen backbone). Finally, it will be concluded that these climate technology solutions (currently in industrialization phase) are ready to serve installed plants, at the same time minimizing the impacts on greenfield plants.

Hydrogen in Canada is beginning to shift from hypothetical debates to practical demonstration projects and large-scale production facilities. Several challenges have been identified when it comes to instrumentation and measurement of the hydrogen molecule With pipelines blending 5-20% Hydrogen into natural gas systems, and pure H2 pipelines being planned, these challenges need to be solved to safely transition to a Hydrogen economy. Whether unique material considerations or different analytical techniques for purity analysis and BTU analysis, these challenges manifest differently at each stage of production of hydrogen and its various downstream uses This presentation will cover an extensive portfolio of measurement solutions to solve the biggest measurement challenges, including: - Quantification and measurement of Hydrogen in production facilities - Meeting sold-to-market pipeline specifications for Hydrogen purity - Hydrogen-appropriate metering technologies - Accurate control of Hydrogen blending process for precise custody transfer.

Hydrogen Embrittlement in Metallic Storage and Transport Materials: A Focus on Macro Effects As the world’s energy infrastructure begins the process of adapting to greater scales of hydrogen transport and storage, research continues to explore and evaluate the limit of hydrogen service capability for new and established products and materials. Much work has been done over the last 20 years to understand the fundamental mechanisms behind the embrittlement and permeation tendencies of metallic materials when exposed to hydrogen. However, while much work remains to be completed in this area, even more work remains to uncover the effects of hydrogen at the macro level. In this presentation, macro material and product effects in hydrogen, both established and potential effects for storage and transport applications, will be discussed. The presentation will begin with a brief review of the fundamentals of how metallic materials respond when exposed to hydrogen. These fundamentals include the engineering properties most used when designing and evaluating high-pressure gas storage and transport systems. This introduction will be followed by a description of several macro material or product properties that have either been established as being affected by the presence of hydrogen, or that have the potential to be affected and consequently require additional research. Examples of relevant macro properties that will be touched on include surface finish, local hardness, and residual stress, among others. Direct or analogous case studies of gas system failures related to macro effects will be recounted. Similarly, research conducted on the impact of macro effects in high-pressure gas systems as they relate to hydrogen transport and storage will be summarized, presented, and discussed. Finally, recommendations for future research will be provided.

Industrial players around the world and locally have begun to declare their commitments to a net zero greenhouse gas emissions future. This has prompted energy producers and consumers alike to think beyond the status quo and innovate for how we will power the future in a clean, safe, and reliable manner. In a time where global economies are highly dependent on the movement of commercial and consumer goods, the decarbonization of heavy-duty transportation is a key lever in the energy transition. Hydrogen propulsion systems have shown major promise to progress this future in the short and long terms, with dual fuel engines, high pressure direct injection engines and fuel cells being front runners in that space. This presentation will provide a framework for the technoeconomic evaluation and comparison of technology options for decarbonizing heavy haul transportation considering key life cycle characteristics. This encompasses technologies beyond hydrogen such as battery electric, renewable fuels, and carbon capture for mobile applications. In a sector with several competing alternatives emerging as next generation haulage, it is important to consider and optimize every step in the hydrogen life cycle from production to pump. Examples will be shared to demonstrate how to develop key inputs for a cost benefit technoeconomic assessment, recognizing sensitivities to assumptions that have a material impact on the fuel’s carbon intensity and levelized cost. Technologies like hydrogen dual fuel can help first adopters reduce emissions while developing the infrastructure required to establish a national fueling network. This will provide the necessary runway for hydrogen fuel cell technology developers to advance their technology solutions such that they can meet the cost and range requirements expected by the industry. The presentation also pays attention to the challenges and opportunities associated with “changing the game” in a well-established sector and the need to broadly engage stakeholders as part of the innovation journey bridging gaps between major players across the value chain. Opportunities associated with regional partnerships will be discussed. Significant economic value can be leveraged from bringing together industry alliances that are designed to collaboratively develop the supply chains, logistics, and infrastructure required to enable hydrogen as a transportation fuel. Research and analysis have outlined the importance of being a leader in this field in order to acquire market share. This presentation offers a perspective and approach in which analytical rigor and technoeconomic insights can help inform and shape decision-making.

Industrial Hydrogen markets are dominated by upgrading, petroleum refining and ammonia production. Steam methane reforming (SMR) is the current industry standard and lowest cost option for large-scale H2 production but generates substantial GHG emissions, which are costly to mitigate using CCS. By contrast, green H2 solutions using electrolysis are attractive for their ultra-low emissions, but are energy intensive and expensive. This paper will highlight the development and validation of a scaled, methane pyrolysis solution that delivers decarbonized H2 at costs on par with current industry practices and provides a pathway for scaling up clean H2 solutions worldwide. Ekona’s novel pulsed methane pyrolysis (PMP) solution converts NG into H2 and solid carbon with virtually no CO2 emissions. The pyrolysis reactor uses pulsed-combustion and high-speed gas dynamics to thermally crack methane. This disruptive solution is low-cost, scalable and solves carbon fouling issues that plague other strategies. The PMP reactor can be integrated with industry-standard balance of plant for H2 purification and carbon separation, simplifying industrial process integration. Since the PMP produces solid carbon, siting is not reliant on CCS infrastructure. Moreover, since water is not required, the PMP can be located wherever NG infrastructure exists. Ekona’s PMP produces industrial H2 at costs comparable to incumbent SMRs, while reducing GHG emissions by 90%. Ekona has completed testing of a proof-of-concept (PoC) reactor. The PoC test rig incorporated electric heating and single-batch operation in a laboratory-scale test article. PoC test results confirmed fundament design principles and physics and validated concurrent modelling. Leveraging this success, Ekona is presently executing a 3-phase technology development project that will (a) build and test a prototype 200kg/day H2 PMP reactor, (b) assemble a PMP brassboard system to evaluate process integration and (c) commission a fully integrated PMP system. This presentation will review the design methodology and results of steps (a) and (b). Scale up of the PoC system began in early 2021 leveraging a rapid batch architecture whereby the reactor would be fed by heated feedstock whose temperature is elevated further through use of side-mounted combustors. Said combustors inject hot products into the reactor to provide the additional heat of reaction to complete pyrolysis. Extensive chemical kinetic modelling and Computational Fluid Dynamics were leveraged to guide the design re requisite mixing schemes, optimal fluid dynamics to ensure efficient combustor usage and filling/purging cycles, quantify requisite operating conditions and predict both hydrogen and carbon yields including soot morphology. After system tuning, it was found that actual hydrogen and carbon yields were commensurate with model predictions to enable validation of the scale up methodology but more importantly, it permitted verification of calibrated design tools for further scale up to more commercial sizes for eventual product deployment.

Advancements in sensor technology and artificial intelligence (AI) have enabled significant evolution in asset integrity monitoring capabilities, perhaps most notably in the area of pipeline leak detection and integrity management. Combining the exceptional sensitivity and lightspeed transmission capabilities of distributed fiber optic sensing (DFOS) with the analytical horsepower of the latest machine learning (ML) strategies allows pipeline operators to accurately detect and characterize even minute integrity events (like pinhole leaks) in real-time, regardless of when or where these occur within their vast asset networks. Due to the above, DFOS has experienced strong commercial growth in the traditional oil & gas midstream sector; however, there are several key considerations expected to influence its adoption and operational effectiveness for the pipeline transportation of hydrogen. This presentation will describe advances in machine learning-based leak detection and integrity monitoring, as well as cutting edge application of AI & ML tools for event simulation (leveraging ‘deep fake’ models), and multi-source data fusion for enhanced protection and performance of critical pipeline assets. Practical extension of DFOS systems and the noted advances to hydrogen pipelines will be discussed, with a focus on the drivers (including the product-agnostic nature of fiber optic sensing and its inherent ability to support stringent regulatory and reporting standards via the provision of rich data sets and advanced analytics) as well as the challenges (including consideration of hydrogen’s unique properties in the development of supporting algorithms and the technoeconomic implications of leveraging DFOS for the repurposing of existing pipelines for hydrogen transport) that will collectively determine the real-world potential of DFOS to meaningfully support the energy transition. A robust approach to pipeline integrity management employs multiple orthogonal algorithms which aim to identify specific events ? leaks serve as excellent examples - using independent methods. Both Supervised and Unsupervised Learning approaches, as well as the underpinning Neural Networks, will be discussed in the context of simulation and characterization of event signatures during both baselining and subsequent operational monitoring of pipeline assets. Factors unique to hydrogen (and CCUS) pipelines that must be considered in the development and application of these algorithms will be reviewed, including, for example, the impact of a varying Joule-Thomson effect on interpretation of thermal events associated with hydrogen leaks. In addition to the noted innovation in pipeline monitoring, the presentation will also touch on the technical and economic considerations associated with the development ?" or repurposing ?" of grid-scale pipeline infrastructure for hydrogen transport, with the goal of providing novel insight regarding technology solutions to address anticipated regulatory and societal concerns as hydrogen moves rapidly into our cities and homes.

Objectives/Scope: This study assesses strategies to decarbonize road transport in Alberta, including carbon pricing, zero-emission vehicle mandates, and zero-emission vehicle incentives. The objective is to analyze and compare these strategies' effects on vehicle shares, energy demand, greenhouse gas emissions, and transport costs by 2050. The analysis considers the impacts on the province-wide energy system: quantifying all direct and indirect energy system impacts. Methods, Procedures, Process: The road transport sector and indirect energy sectors are modelled using a first principles modelling approach. The sector comprises 10 vehicle categories: cars, sport-utility vehicles, pickup trucks, vans, school buses, intercity transit buses, urban transit buses, light freight, medium freight, and heavy freight. The province-wide analysis includes a complete energy supply chain analysis, with the upstream energy and emissions associated with each fuel, including resource extraction, conversion, transmission & distribution, and fuelling. Alternative electricity and hydrogen supply systems are evaluated, such as grids with different levels of renewable electricity and hydrogen production with carbon capture and sequestration through steam methane reforming and autothermal reforming. Results, Observations, and Conclusions: Carbon prices and zero-carbon vehicle incentives do not significantly impact the province's vehicle shares or greenhouse gas emissions between now and 2050. Zero-emission vehicle mandates are needed to have a significant effect. The emission factors for hydrogen fuel cell and battery electric vehicles are significantly below conventional gasoline and diesel vehicles in all alternative electricity and hydrogen supply systems. Novel/Additive Information: To the best of our knowledge, it is the first study that considers hydrogen production by auto-thermal reforming with carbon capture in a long-term greenhouse gas emissions analysis. We analyzed provincial market share, vehicle costs, energy demand and greenhouse gas emissions from different scenarios. We believe this to be the most comprehensive analysis of the road transport sector. We provide insights for policymakers and consumers.

In auto-thermal reforming for hydrogen production, methane is partially oxidized by pure oxygen. The resulting heat from this process then drives an endothermic steam reforming reaction. Conventional ATR process design includes an Air Separation Unit (ASU) to generate inlet oxygen stream for autothermal reforming process. ATR enables high carbon capture rate for blue hydrogen production, but ASU is capital and energy intensive. For this reason, ATR typically would require larger scale to achieve economical scale. The proposed approach considers hydrogen generation via a combined electrolysis and ATR system. The electrolysis process splits the water into hydrogen and oxygen molecules. The generated oxygen and hydrogen gases are collected at the electrolyzers as separate gases. The produced oxygen is collected for use and compressed to be sent to the ATR. For a 200 TPD hydrogen plant with the combined approach, there would be 60 TPD from electrolysis and the balance from ATR. The combined approach utilizes “free” oxygen from electrolysis as feedstock to ATR and therefore eliminates capital and energy consumption associated with ASU. It also offers feedstock flexibility and optimization opportunity to meet target carbon intensity (CI). In an area where hydrogen demand is developing, the combined approach provides opportunities for a phased approach. The electrolysis could start first to meet immediate demand while waiting for the market to catch up. TC Energy is developing a project using the combined ATR + electrolysis with a phased approach. A project update will be provided as part of the presentation.

Thermophysical property data for pure hydrogen and its related mixtures is essential to the design of process equipment required for production, liquefaction, storage, and transport. The selection of equation of state is imperative for proper H2 system design. This presentation will present two case studies highlighting the challenges of using commonly available equations of state (i.e., PR78, SRK, GERG2008) and how the lack of data of hydrogen mixtures necessitates the overdesign of gas/liquid handling facilities. The first case study will investigate the sensitivity of liquid H2 boil-off gas to unloading system design and the impact the choice of EOS has on vapour-liquid equilibrium prediction. The outcome will quantify the relative uncertainties to be anticipated in system design based on common EOSs using commercial process simulator software. The second case study will review the first phase of a joint industry-academia research project Wood is supporting that seeks to better understand the limitations of current EOSs in predicting the properties of hydrogen natural gas mixtures. Findings from the liquid H2 unloading study indicate that the GERG2008 and PR78A are in better agreement. The CPA EOS overpredicts the boil off rates of gas formed in the flowline. Consequences of overpredicting the gas boil-off rates may lead to over design of the vapour handling systems associated with the liquid H2 unloading system. Preliminary findings from the joint industry-academia research project into thermodynamic properties of hydrogen natural gas mixtures indicate the EOS accuracy is insufficient for reliable mass flow metering (within 1%). Further, a dearth of data, large deviations, and lower model performance has generally been observed for transport properties. The viscosity and thermal conductivity predictions can exceed 25% deviation. Deviation on this order, when coupled with density prediction errors, can lead to pressure drop prediction errors greater than 5%. This work discussed here presents some of the first investigations into the quality of the data and models available for the design of hydrogen-containing transport systems that rely on accurate predictions of the thermodynamic and transport properties. This work is in its infancy but will be essential for the reliable design for hydrogen transport system in support of global decarbonisation goals.

In the race to transform and green our energy systems, hydrogen blending is growing at an exponential rate. Greener hydrogen blended with natural gas can deliver cleaner, zero-emission energy for industry, commercial, and household uses. This presentation provides the results of two recent • global studies that provide a comprehensive review of over 100 projects and hundreds of technical and research papers addressing technical and other challenges in blending. The presentation will provide the state of the art regarding current blending challenges and the extensive work that is being done to address these challenges. Both studies were led by the author with a team of experts collaborating with dozens of subject matter experts from many global and North American utility companies and research organizations.

The hydrogen market is forecasted to grow globally one thousand-fold by 2040, with demand for clean hydrogen projected to reach 500 million tonnes a year between now and 2050. Low carbon hydrogen has the potential to decarbonise chemical, cement, iron and steel production and provide combined heat and power from a single source. Hydrogen will enable surplus energy from other sources to be stored and circulated across sectors and regions, creating a circular economy of renewable energy where wasted energy is continually recycled into power. It’s also a prime electrofuel, to rapidly decarbonise sectors such as shipping and aviation. And crucially, hydrogen can provide renewable fuel for sectors from freight transport and shipping, where unsuitable for direct electrification.

The international climate agreements have kicked off a high demand for clean hydrogen. Significant government funding since 2020 have accelerated this demand. Finally, new strategies and investment announcements of major high emitting industries, like oil & gas, chemicals and transport as well as the financing industry are boosting that demand.

This has resulted in a growing gap between supply and demand, with the world needing 10 times more projects and investments into green and blue hydrogen as per today. This is driving increasing demand for more competitive levelised cost of hydrogen and its derivatives, to encourage the necessary investment in extra capacity.

But, how to implement complex long term investment projects in an environment of high uncertainty?

This presentation will discuss the importance of the pace of implementation, techno-economics decision making in an uncertain world, and cost synergies required to enable a seamless integration of diverse projects, partners, people, and processes.

Fuel cells are an established, mature zero-emissions technology for heavy duty powertrains and their value for bus and truck applications is being recognized with growing investments by industry leading original equipment manufacturers. It’s clear that hydrogen will be a key player in the decarbonization of the heavy-duty transportation sector. Hydrogen fuel cell technology has come a long way from the early days. The technology has accumulated significant operational, reliability, and durability data through commercial operation in fleets. Over 3,600 Ballard-powered fuel cell buses and trucks are deployed today. To date, commercial trucks and buses with Ballard fuel cell technology inside have travelled more than 100 million kilometres on the road. However, the adoption of fuel cell heavy duty vehicles is still limited considering there are millions of buses and trucks on the road with a growing contribution to GHG emission. Barriers to adoption include technology cost, availability and affordability of hydrogen and its infrastructure as well as limited number of hydrogen truck platforms available today. Furthermore, hydrogen fuel cell is not the magic bullet which will allow us to immediately transition from internal combustion engines to zero emission vehicles. We are going to need a combination of technologies including batteries to achieve the ambitious goal to be carbon neutral by 2050 in Canada. Therefore a use case approach is more suitable focusing efforts on applications where hydrogen is most suitable. In this session, we will look at a Total Cost of Utilization (TCU) driven approach with fleet operator could accelerate initial adoption. We will look at the case of transit bus and heavy duty truck to better understand the use cases where hydrogen powered vehicles deliver the most value to customers. We will also look at concrete step that Ballard is taking to improve TCU through technology innovation, hydrogen energy systems integration and partnerships with vehicle integrators. Through this session, you will gain a deeper understanding of Ballard’s technology and partnership roadmap to accelerate adoption of hydrogen for heavy duty mobility. Within this decade fuel cell heavy duty vehicles will offer the most attractive TCU compared to battery electric vehicle or an internal combustion engine vehicle for specific applications.

In recent years, there has been considerable pressure to decarbonize the refining industry, in particular by replacing the existing Steam Methane Reformers (SMRs) with either blue (fossil fuel-based technology that includes CO2 capture) or green (renewable energy based) hydrogen generation technologies. Hydrogen already plays a significant role in the refining industry in the process of hydrocracking, which involves converting high-boiling point hydrocarbons into low-boiling point products such as gasoline, diesel, and jet fuel. Refineries are a natural fit for the emerging low carbon hydrogen industry as they provide steady, large-scale demand for hydrogen from potential hydrogen hubs. One factor in the switch to low carbon hydrogen production which the authors have not seen considered or quantified is the potential impacts on reliability and availability, which is of particular importance given the steady hydrogen demand profile of refineries. This paper discusses the impact on plant availability of replacing the current grey hydrogen generation through SMR with either the blue solution (Autothermal Reformer or SMR with carbon capture) or the green solution (electrolysis). The analysis was performed using TARO, a DNV developed software commonly used in RAM studies in the downstream industry. In this study, blue hydrogen is discussed in relation to its impact on refinery reliability, the requirement for storage to meet hydrogen demand, and the potential requirement to vent CO2, which will have an impact on overall plant emissions. For the green hydrogen case, a hydrogen production system based on electrolysis considers the reliability of individual modules and the overall electrolyzer plant, the need to overdesign the electrolyzer plant to allow for maintenance and replacement of the module, and the impact of renewable energy variability on hydrogen production. For both solutions, hydrogen storage requirements are assessed in order to meet refinery hydrogen demands and match typical availability of 98%.

Methane Pyrolysis Lifecycle Assessment Hycamite TCD Technologies is a company based in Kokkola, Finland that has developed the technology to produce clean hydrogen and valuable solid carbon. This is achieved by splitting methane from natural gas and biogas via thermocatalytic decomposition (TCD), which is a form of methane pyrolysis that utilizes catalysts. The scope of this abstract is to highlight the potential of combusting hydrogen, produced from methane pyrolysis, to reduce greenhouse gas (GHG) emissions from the maritime industry. The solid carbon formed in the process can also be used to reduce GHG emissions from the battery industry. It should be noted that the results from each of these research studies did not allocate the emissions to two products thus the final results are lower than what has been presented in this abstract. In the spring of 2022, a literature review was conducted for Hycamite on the well-to-tank (WTT) lifecycle assessment (LCA) (based on the ISO 14040 standard) of liquid natural gas (LNG) used in the maritime industry. The practical part of the LCA included a tank-to-well (TTW) analysis on how blending hydrogen with LNG reduces the GHG emissions from this industry. This was completed as a master’s thesis research. Results from the study showed that, if 100% hydrogen is combusted, it has the potential to reduce emissions from the whole lifecycle by up to 68%. This is close to the International Maritime Organisation (IMO) 2050 target of 70% CO2 emissions reduction. When only emissions emitted from the ship are considered then emissions can be reduced by up to 100%. The research further concluded that there is potential for onboard hydrogen production, via the TCD process, by using the existing bunkering LNG infrastructure. A second master’s thesis research was conducted in the summer of 2021 on the carbon footprint of the solid carbon produced from the TCD process of methane. The emission factor was calculated on the basis of a report by Gasum Oy, where ISO 14040 and ISO 14044 standards were used to calculate the results. The final results revealed that the carbon footprint of the carbon was approximately 0.882 kg CO2eq/kg C. There is increasing pressure in the maritime industrial regulations to decrease CO2eq emissions. It is imperative that the use of conventional fuels such as LNG is reduced and the use of alternative fuels and technologies (such as hydrogen from methane pyrolysis) is taken up. The solid carbon co-product from methane pyrolysis can also be used to decarbonize various industries, such as the battery and cement industries.

As the world looks to decarbonize, hydrogen has emerged as an important new fuel that will play a significant role in the energy transition. Pipeline companies that need to safely transport pure hydrogen near populated areas will require odorants to be added to the hydrogen stream in accordance with federal regulations, however the odorants that have typically been used for dosing natural gas streams are sulfur-containing. This is not problematic if the hydrogen is going to be used in combustion applications in place of methane, but if the hydrogen is to be used in fuel cell applications the presence of sulfur will have a negative effect on the health of the fuel cells. As a result ? new odorants are needed that do not contain sulfur, have a suitable olfactory impact, and can diffuse fast enough to “keep up” with the hydrogen diffusion front in the event of a release. By applying fundamentals of gas odorization, Enersol has identified several non-sulfur odorant compositions that are expected to perform across the various dimensions of the hydrogen odorization application, and Spartan Controls has evaluated the compatibility of these odorant compositions with our IOTA-PI odorant injection solution in a hydrogen odorization application. This presentation will provide an overview of Enersol’s analysis of hydrogen odorants, and an overview of the IOTA-PI odorization solution.

Atura’s Objective is to be the leader in low-cost, clean hydrogen production in Ontario starting with the 20MW Niagara Hydrogen Centre (NHC), the largest electrolysis system in Ontario, and second of its size in Canada. Atura will advance beyond this initial project to develop multiple hydrogen production hubs within the province, acting as a catalyst for broader industry decarbonization. Atura’s Strategy for leading the clean hydrogen production sector in Ontario is to leverage existing energy infrastructure assets, access to the low-carbon Ontario electricity grid and utilize the requisite project development skillset to identify and develop large scale, collocated production projects with heavy emitting industry counterparties - thereby accelerating and solidifying the clean hydrogen economy in Ontario. Atura has identified 5 hydrogen hubs across Ontario that are ideally suited for immediate hydrogen adoption. NHC is the first action listed in the Ontario’s Low-Carbon Hydrogen Strategy, with the development of the 5 hydrogen hubs the second action. The Niagara Hydrogen Centre proposes to support the Ontario low-carbon electricity grid in the form of grid regulation services ? this strategy is an innovative application for hydrogen electrolysis which couples the efficient production of clean hydrogen, as powered directly by the adjacent hydroelectric generating station, with the provision of these ancillary services; taken together, this project proposes to produce hydrogen with the lowest carbon intensity possible, via run-of-the-river hydroelectricity, in addition to supporting that same hydroelectric generating station in maintaining optimal efficiency, while also ensuring that the Ontario low-carbon electricity grid is balanced in real time. The clean hydrogen produced at NHC is planned to be consumed at one of Atura Power’s combined-cycle gas turbine (CCGT) power plants, which will be the first in Ontario and will provide an industry-wide learning opportunity. This vertical integration strategy provides the platform to solve the proverbial chicken and egg issue between hydrogen supply and demand. Beyond consumption at the CCGT facility, the clean hydrogen produced may be made available to wider industrial counterparties to support decarbonization, whether aviation, mobility, chemicals, refining, steel manufacturing, etc. Note 1 - at the time of this presentation, more information is expected to be shared on federal funding, project status (cost & schedule), technical concept and technologies utilized and planned for the project. Available lessons learned on codes & standards, regulatory frameworks, supply chain, technology assessments, etc. can be shared with the attendees to build out the collective knowledge base. Note 2 - by way of proposal, may also want to invite the Engineer of Record, Eletrolyzer Manufacturer and selected General Contractor to showcase the entire project team bringing this clean hydrogen project to Ontario.

Hydrogen is currently being explored as a global low carbon fuel commodity for a variety of novel end-uses to replace fossil-fuel alternatives. Currently, in Alberta and elsewhere, hydrogen is traded mainly as compressed gas over land, for traditional industrial uses, and is not traded at the scale of a global commodity. Hydrogen in the form of a cryogenic liquid, or in the form of carriers such as ammonia, is being considered for overseas export to replace fossil fuels. This paper will explore opportunities and challenges for hydrogen and its potential carriers for export as a global commodity for transportation and power end-uses, with a particular focus on informing Alberta’s investment landscape over the next decade. Ultimately, the aim of this assessment is to demonstrate the trade-offs that must be considered between carbon intensity, energy delivery efficiency, and cost, as Alberta and other jurisdictions seek to replace traditional fossil fuels with hydrogen and its carriers to meet net zero goals. In this paper, we examine a series of cases pertinent to Alberta, within two high level boundary cases: (1) export of product produced in Alberta for end use in transportation applications in Asia-Pacific; and (2) export of product produced in Alberta for power generation applications in Asia-Pacific. We will provide a basic comparison of hydrogen and its carriers in terms of energy density, safety & toxicity, by-products of combustion, by-products of end-use, current commodity cost, and logistics of transportation. We will then calculate and provide a case-by-case, well-to-tank and/or well to plant analysis of key metrics, including: lifecycle carbon intensity, ultimate energy delivery efficiency, and cost. We will use this analysis to identify gaps in technology and data availability. We expect this analysis could lead to follow-on work to accelerate adoption of hydrogen and hydrogen-carrier technologies, such as comparison to other jurisdictions; and ultimately, may be used to enhance Alberta’s competitiveness in the context of a net zero global economy.

Transportation Supply Chain: Immediate and long-term hydrogen use as a fuel source to help industries reach their net zero initiatives is inevitable - consumption is steadily increasing with continual market adoption. The increase in demand has revealed several challenges in the hydrogen supply chain, with specific emphasis on access and effective distribution. Existing gas grids either cannot support or have not yet been shown to support gaseous or liquid hydrogen distribution ?" either as a pure product or as a blended product. Given this reality, hydrogen must be transported from the production location to the end-user location via methods that do not rely on pipelines. Methods include transporting liquid or gaseous hydrogen via ships, high-pressure tube trailers (virtual pipeline), rail, or alternative hydrogen carriers (i.e., ammonia, or methanol). Without meaningful progress in distribution, decarbonization efforts can only progress so far and so quickly. Certarus Ltd. will detail their virtual pipeline solution for safe and reliable transportation of hydrogen. The discussion will focus on how effective virtual pipeline distribution is with current applications and any unresolved or significant challenges currently faced. The main points that will be addressed are: • Are there too few transportation methods with too much demand based on current and future hydrogen projects? • If hydrogen demand increases as projected, is there enough equipment available in the market today to distribute it? • How can hydrogen be incentivized as a cost competitive low-carbon fuel source in North America?

Blue hydrogen continues to play a critical role as a fuel source in both government and corporate strategies for achieving net zero emission targets. Reforming technologies are a proven economic and scalable solution for hydrogen production, provided that an attractive carbon removal strategy is used to minimize fuel carbon intensity and deliver a sustainable approach to hydrogen production. Producers will realize a competitive advantage where technologies and process schemes are selected that reduce the high energy and utility costs associated with carbon capture. The application of large-scale auto-thermal reforming (ATR) hydrogen production coupled with the most recent advances in carbon capture technology can provide one of the most competitive means of producing low carbon blue hydrogen. Commercially competitive carbon capture technologies will be evaluated and compared for blue hydrogen process schemes through a techno-economic analysis. Specific examples will be presented with a focus on the cost of production and resulting carbon intensity of the blue hydrogen product.

Alberta possesses a unique combination of legacy energy sources (conventional oil and gas) and renewable energy. For decades, First Nations communities such as Frog Lake First Nations (FLFNs) have relied on oil and gas extraction for income and employment. As these resources are consumed and the globe focuses on sustainable energy, their economic incomes must be replaced and the impacted lands and waters must be remediated for the benefit of future generations. Alongside this activity, Indigenous communities seek to be the corporation developing sustainable energy solutions. To this end, FLFNs has a multi-generational plan to develop and share green solutions to enhance all Indigenous people’s quality of life. Central to this plan is the Legacy Energy and Alternative Power (LEAP) strategy, and associated corporate body. Low carbon hydrogen is the heart of the LEAP master plan which focuses on community education, training and advancing research and development on promising new technologies that leverage abandoned oil wells, industrial grey water, and cutting-edge renewable power plants and technologies for the production of green, electrolytic hydrogen. Central to the community hydrogen strategy is a focus on developing relationships, partnerships, joint ventures, and projects that position First Nations as leaders in the energy transition. FLFNs’ approach has attracted over two dozen international, national, and regional firms and institutions to help co-design, build, finance, and realize Indigenous-led green energy capacity. Simply put, FLFNs’ approach integrates Indigenous and Western knowledge to advance sovereignty and reconciliation, and clears crucial barriers to hydrogen innovation. Renewable power and hydrogen production are simply the first steps. Together they enable key community priorities such as fuel cell buses, a community micro-grid network, and food sovereignty via hemp production, vertical farming, and green building technologies. These innovations will be amplified through FLFNs’ regional partnerships with Indigenous and non-Indigenous communities. Knowledge and technology transfer to and from the community is also a key pillar of LEAP. Public institutions such as the Southern Alberta Institute of Technology (SAIT) and private sector companies are key partners to develop applied research solutions, training, lifelong integrated learning, and community hydrogen education. The funding leverage for collaborative projects between Frog Lake, corporations and SAIT are key to developing and implementing the LEAP plan. Collaborative projects between Industrial, institutional, and financial partners will continue to underpin the LEAP strategy. This presentation will outline the 14-point LEAP plan and highlight opportunities for collaboration with diverse private and public sector allies.

As the world pushes to reach net-zero emissions and fight climate change, hydrogen represents a key alternative to achieve these goals. With that expanding role, transportation of gaseous hydrogen through pipelines requires further analysis to ensure proper design and safety standards are maintained. For instance, due to poor maintenance or aging, pipe ruptures might occur. These events and the resulting jet loads can cause catastrophic damage to neighboring components or pipes. Although models that estimate the jet impingement loads exist in the literature, further effort is required to overcome their non-conservatism and inaccuracies. In the current study, Computational Fluid Dynamics (CFD) is used to investigate the characteristics of jets that emerge due to ruptures in high pressure hydrogen pipelines. This effort attempts to offer a more accurate approach for evaluating the loads on neighboring pipes that arise following such an event. Specifically, a 3D multiphysics model is developed using ANSYS Fluent. The model accounts for a number of highly coupled physical processes including compressibility, supersonic flows, which can result in shock waves that causes high impact forces on adjacent pipes, turbulence, and heat transfer. The conducted simulations were found to accurately predict the jet characteristics and behavior. Furthermore, the model was used to assess the impact forces on neighboring pipes and their dependence on different parameters including pressure, pipe diameter, and geometrical aspects of the break area. The outcome of the current study is expected to offer a better understanding of the consequences that result from postulated hydrogen pipeline ruptures, which can help improve the safety of hydrogen transportation.

Objective / Scope: Proteum Energy™ produces clean hydrogen from any natural gas liquid (residue gas blends preferably with ethane) and oxygenated hydrocarbon (methanol or ethanol) using its proprietary Steam Non-Methane Reformation (SnMR™) process. The modular and scalable system (15-150 TPD) produces clean hydrogen at an operational cost and CAPEX cost/kg that is competitive with conventional steam methane reformation, but with a lower produced hydrogen carbon intensity (CI). By integrating off-the-shelf optional processing modules, system product gas mix can be varied according to site requirements with products ranging from fuel cell grade hydrogen only to combinations of hydrogen, methane, and CO2, including hydrogen-methane rich designer fuels tailored to meet Wobbe Index, Methane Number, and heating value requirements. Methods / Procedures / Process: Rather than using methane as a feedstock, the system utilizes lower-value hydrocarbons including stranded or rejected ethane to produce hydrogen, methane, and designer fuels. The lower-cost feedstock in combination with reduced energy requirements allows Proteum to produce clean hydrogen at low cost. Integrating the proprietary SnMR™ technology with off-the-shelf ancillary process modules, like amine systems for CO2 removal, PSAs for H2 removal, and SNG modules for pipeline quality methane production enables Proteum’s system to be adapted for many use platforms. Examples of these Platforms are 1) direct pipeline hydrogen injection, 2) SAE J2719 fuel cell grade transportation hydrogen production, and 3) direct hydrogen fuel blending for turbines, reciprocating engines, or any gas-powered prime mover. Results / Observations / Conclusions / Novel Approach: Lower Cost and Carbon Intensity - Operating costs are lower than steam methane reforming (SMR and ATR) with lower CAPEX per kilogram. Carbon intensity (pre-CCS) produced clean hydrogen from ethane is approximately 57 gCO2e/MJ. The carbon intensity of produced hydrogen from ethanol is modeled at -46gCO2e/MJ for negative CI H2. Platform Flexibility: Reforms any non-methane hydrocarbon or oxygenated hydrocarbon to produce clean hydrogen, methane, and hydrogen-rich designer turbine fuel. Proteum’s system offers product gas flexibility ranging from ultra-low carbon fuel cell grade renewable hydrogen. Wobbe and Heat Index adjusted to meet exact specifications, including Load Following capability. Lower CAPEX / OPEX / kg: Truck-ready shop-built modular design. Standardized 306 stainless steel flange construction. Less than 1MW is required, per standard system, for site power. No need for purity grade water and recycled system water means lower water consumed than SMR and electrolysis. Lower Produced Hydrogen Carbon Intensity: Due to 1) fundamentally lower energy requirements, 2) low CI feedstock availability with methane as a co-product and, for renewable hydrogen production, and can utilize lower CI (80-100 proof ethanol beer cut) feedstock, 3) leveraged waste heat recovery 4) low power requirements and, 5) lower water consumption than either SMR or electrolysis.

Many industries have committed to decarbonizing their value chain to meet 2030 and 2050 targets of keeping global temperatures below 2°C by switching from traditional fossil fuels to alternative fuels such as biodiesel, renewable diesel, renewable natural gas, ammonia, hydrogen, and direct electrification. In the quest for zero emissions, biomass-based options may be less favored as their lifecycle carbon intensity can be higher than renewable electricity-based options such as direct electrification, green hydrogen, and green ammonia. Specifically, there has been an increase in interest for green hydrogen, mostly due to its ability to be used to a fuel (e.g., hydrogen vehicles), feedstock (e.g., refining), chemical carrier (e.g., ammonia), and reductant (e.g., steelmaking). Green hydrogen can be generated using water and renewable electricity from solar or wind through electrolysis, and unlike traditional production pathways such as natural gas reforming and, more recently biomass gasification, does not require a solution for carbon dioxide which is produced as a co-product in these processes. Many industries are depending on green hydrogen to reach their decarbonization targets, and the International Energy Agency (IEA) expects 130 Mt H2 to be required by 2030 under their announced ambitions and targets (APS) scenario. Canada has demand targets of 4 Mt H2 for 2030 and 20 Mt H2 for 2050. Comparing these scenarios with the status of green hydrogen projects that are currently under final stages of design, construction, commissioning or in operation, will highlight a gap between how much installed electrolyzer capacity is required in the future to meet our global net zero targets and how much is currently available. If the current rate of electrolyzer development is followed, there will not be enough capacity to reach Canada and IEA targets by 2030 and/or 2050. In other words, are we behind in our implementation of green hydrogen and can we get back on track? This presentation will assess the reality of green hydrogen supply and whether these targets are achievable based on the current rate of development. It highlights the heightened interest in green hydrogen, the gap between the forecasted supply and demand, and what actions are needed to ensure targets are met. The underlying factors that are contributing to the gap, including technology development, supply chain readiness, permitting, and financial requirements will be evaluated to identify actions that will accelerate the adoption of green hydrogen in the future.

Diesel Tech Industries decarbonizes the transportation industry through its multi-port hydrogen dual-fuel injection system. After talking with numerous clients and partners, our solution provides a dual-fuel hydrogen blending solution with our new proprietary multiport injection system, paired with our own full ECM integration and control system. The Guardian Hydrogen Diesel system will include fully integrated Guardian HDS hydrogen storage vessels. The onboard H2 storage vessels and mounting frame will be engineered to ensure the minimal amount of weight is added to the vehicle.

A mass and energy balance (from commercial scale pilot plants) is provided for the production of low CI hydrogen from methane or biogas using a high performance catalytic process. Catalyst yield achieved is 150 grams of high grade crystalline graphite per gram of catalyst, with the corresponding stoichiometric amounts of hydrogen. No by products are produced. Energy required to achieve reaction energy, gas purification, cooling, etc., is provided as a parasitic load of ~ 40% of produced hydrogen. 100% of the methane is cracked and converted to carbon and hydrogen. The process can use either biogas or pipeline natural gas and produces hydrogen from pipeline gas with a CI of less than 1 Kg-CO2/Kg H2 and a severely negative CI based on the source of the biogas.