As the world shifts towards sustainable energy sources, the imperative for effective carbon dioxide (CO2) capture technologies in hydrogen production by reforming facilities becomes increasingly evident. This transition encompasses a spectrum of methodologies, with notable solutions including amine wash, hot potassium carbonate solution, physical solvent-based processes, and cryogenic techniques. Each method presents unique advantages and considerations tailored to specific application scenarios. The amine wash method employs specially formulated amine solutions to chemically absorb CO2 from syn gas streams, subsequently releasing it within a desorber column. Similarly, the hot potassium carbonate solution utilizes potassium carbonate as a chemical scrubbing agent, with CO2 release occurring within a desorber column at elevated temperatures. In contrast, physical solvent-based processes rely on physical absorption at high pressure to separate CO2 from syn gas streams, followed by desorption to isolate the CO2. Cryogenic techniques, on the other hand, leverage low temperatures to condense CO2 into a liquid phase, facilitating separation within a distillation column. These methodologies yield CO2 with purity exceeding 99% (dry basis) and varying recovery rates from 95% to 99.5%, meeting diverse gas treatment requirements and CO2 product specifications. However, the selection of an appropriate approach hinges on a multitude of factors, encompassing economic viability, technology readiness level, and project objectives. In the realm of high purity blue hydrogen production, large-scale Pressure Swing Adsorption (PSA) systems assume a pivotal role. Two configurations—front-end and back-end PSA—offer distinct advantages, ensuring continuous hydrogen supply and optimizing CO2 separation system size. The choice of CO2 capture technology profoundly influences the project economics, plant on-stream factor and reliability of the plant. Solvent-based systems, for instance, facilitate downstream PSA by producing a CO2-depleted stream, thereby reducing PSA size. Conversely, cryogenic-based CO2 capture poses challenges in equipment volume and cost to handle large volume of syngas, demanding meticulous evaluation. However, with a front-end PSA configuration, cryogenic technology may offer several advantages. Economic analyses, including comprehensive cost-benefit assessments and risk analyses, guide the selection of the Best Available Technology (BAT) for each project. These evaluations, conducted by experts in the field, ensure alignment with project scopes and objectives. Through meticulous consideration and strategic implementation, the integration of effective CO2 capture technologies in a green filed blue hydrogen production or retrofitting to an existing grey hydrogen production facility holds promise for a greener and more sustainable energy future.

This session will explore the collaborative efforts of the Wabamun Hub, highlighting its community and Indigenous partnerships. Learn about the International CCS Knowledge Centre's pivotal role in advancing helping advance carbon capture and sequestration (CCS) projects. We will discuss the shared ambitions for proper public engagement, ensuring transparency and trust in CCS project development.

The Pathways Alliance has completed a global scan of new and novel carbon capture technologies which have the potential to provide superior technical performance and economic benefits relative to the existing capture technologies for potential deployment in the oil sands. This presentation will provide an overview of the study methodology, key findings and planned next steps.

CO2 geologic sequestration projects have two primary monitoring objectives: 1) passive seismic monitoring for induced seismicity that may be caused by injection operations, and which may be indicative of caprock failure, and 2) imaging the CO2 plume extent using active seismic surveys, either in the form of 3D VSPs or active 2D or 3D surface seismic. 3D VSP surveys can be an economical alternative, however the extent to which the plume can be imaged is limited by the depth of the observation well and that well’s proximity to the injection well. 2D surface seismic can also be an economical alternative for sequestration projects with very low injection rates, however a 3D image will provide the best opportunity to image the plume, and in particular map the CO2 as it finds the pathways of maximum permeability in the reservoir. We propose that an array suitably designed to address the first objective, i.e., induced seismicity that may be caused by injection operations, can also provide an adequate receiver array to perform a cost-effective time-lapse 3D survey to address the second objective, i.e., map the CO2 as it finds the pathways of maximum permeability in the reservoir. The requirement to track the CO2 plume is driven by the following: 1. Confirm compliance with the submitted and approved sequestration plan. 2. Confirm reservoir conformance. 3. Deny leakage concerns both shallow and deep. 4. Deny any pore space trespass. 5. Allocate royalties. 6. Verify tax credit qualification. To address injection monitoring induced seismicity objectives, we propose the installation of a permanent BuriedArray of 3-component geophones, with the ability to detect induced seismicity with a magnitude of completeness of approx. Mc = -2, accurate to better than 50 ft vertically, and better than 25 ft horizontally. The system enables a traffic light protocol to be employed, so that operational decisions can be made based on real-time data. The cost of an active 3D survey using conventional surface geophones is significant, requiring extensive field operations related to the deployment and retrieval of surface recording stations, with associated personnel and equipment. These costs can be substantially reduced by utilizing the permanent BuriedArray as a fixed receiver array and making use of source-receiver reciprocity to achieve CDP fold sufficient to provide an accurate subsurface image.

Mitsubishi Heavy Industries, Ltd. (MHI) developed the high-efficiency post-combustion CO2 capture technology known as the KM CDR Process (TM) with Kansai Electric Power Co., Inc. (KEPCO). As of May 2024, eighteen commercial plants with CO2 capacities ranging from 0.3 tons per day to 4,776 tons per day had been delivered around the world. This process efficiently captures CO2 from various facilities, including power plant flue gas, and is contributing to the energy transition. Specifically, MHI demonstrated very high CO2 capture (over 99%) in a long-term test campaign at the KEPCO / MHI pilot plant and Technology Centre Mongstad (TCM), Norway, in 2021. ExxonMobil and MHI entered a carbon capture technology alliance in 2022. Leveraging strengths of both companies to meet customer needs, ExxonMobil and MHI will each provide strength in CO2 capture technology and CO2 transportation/storage, respectively. In addition, work together to develop next-generation liquid amine technology for CO2 capture. This joint effort will ensure all customers have a comprehensive end-to-end solution to drive a low-carbon future. Not satisfied with operating numerous commercial plants, KM CDR Process (TM) continues to improve to reduce energy consumption, CO2 capture cost through further development of proprietary solvent and optimization of the process system." Below are the recent notable updates: 1. Conducted pilot tests on various facilities such as biomass, waste, gas engines, ships, cement plants, steel plants, wood pellet plants, etc. Based on these results, an appropriate design approach was established for each flue gas, considering the effects of impurities in flue gas and its countermeasures. 2. Conducted many integration studies with cement plants, FPSOs, ships, CCGTs, and others. These integration studies include optimizing the heat recovery system between the host unit and CO2 capture and treating flue gas impurity removal. 3. Launch a new commercial plant in Bangladesh using KS-21(TM) and a commercial unit in Italy for gas turbine flue gas. The Bangladesh plant has a unique feature, which is the capability to utilize both KS-1(TM) and KS-21(TM). For the commissioning stage and beginning of commercial operation phase, KS-1(TM) is used, which has significant proven operation record, for stable plant start up purpose. KS-21(TM) is used after the stabilization of the plant operation. This presentation focuses on updating the Advanced KM CDR Process (TM), especially the pilot test result for cement flue gas, and lessons learned from the first commercial plant using KS-21(TM) in Bangladesh and the Italian CO2 capture unit for gas turbine flue gas. Finally, MHI would like to introduce "MHI Low Carbon Solution Canada ULC," which was recently established in Calgary to focus on the CCS business in Canada. Working closely with Mitsubishi Power Canada, the MHI group is willing to contribute to the energy transition in Canada.

As CCUS incentive programs advance around the world, project developers face the difficult decision of where to invest their capital. On paper, Canada's, and Alberta's, various incentive programs, funding opportunities, and carbon credit markets appear to place it among the top regions globally for CCUS project development. However, the Canadian investment environment is complex, making comparisons with other regions difficult. To receive the maximum benefit from a project, developers must stack multiple tax credits, grants and marketable offsets, rather than relying on a single mechanism such as the US 45Q tax credit. Furthermore, several of these incentives have not yet passed into law or have not been made widely available, resulting in uncertainty among investors. Our research will reduce this uncertainty by providing clarity around which incentives would be required to be stacked to provide a profitable business case for various CCS project types, and how that profitability would be impacted if any of the announced programs were not realized. Scope: We will provide an analysis of the average abatement costs for a variety of emitter types in Alberta on a levelized cost of capture, transport and storage (LCOCCS) basis. Project types analyzed will include gas power plants, gas processing plants, steam generation for oil production, blue hydrogen and ammonia production, and cement plants. We will provide an analysis of the impacts of announced incentives and policies including, the proposed federal CCUS ITC, the Alberta ACCIP, historical grant values offered by organizations such as ERA or the EIP, projected values of compliance credits under TIER, the Clean Fuel Regulations and federal credit markets, potential CCfD values offered by the Canada Growth Fund including the Entropy contract and any other contracts signed between now and the event, and tax avoidance impacts based on the projected carbon price under OBPS tax systems. Methods: Using Rystad Energy's LCOCCS models and cost estimating tools, we will model the projected costs of various CCS project types on a cost-per-tonne basis as well as in terms of total operating and capital expenditures, including the purchase and installation of equipment (key to the CCUS ITC and ACCIP). Using publicly available details on the incentives and policies outlined above, we will model their impacts on the capital and operating expenses of the various project types and determine which would be required to realize a negative LCOCCS for a given project, thereby providing a positive return. Conclusions: The outcomes of our analysis will provide a clear understanding of which project types have a promising business case under various announced incentive programs and credit markets. The analysis will also allow for a straightforward comparison of Canadian CCS incentives against other regional programs.

Carbon Capture and Storage (CCS) is a technology that can help to reduce greenhouse gas emissions. However, there are risks associated with CCS;for the storage element, this includes the risk that the storage site is not technically suitable for long-term storage of large volumes of CO2. Key risk factors include insufficient capacity for the anticipated injectate volume, poor injectivity, and loss of containment risk including the potential for measurable CO2 leaks. These risks can be considered as assurance issues – is the CO2 remaining, or contained, within the storage complex delineated by the project developer, and conformance issues – is there an acceptable level of agreement between predicted and measured storage performance? Monitoring, measurement, and verification (MMV) plans are required by regulators and comprise the activities and technology implementation across the project lifecycle to demonstrate the containment and conformance of the injected CO2. The plan must cover the mechanical integrity of wells, including injection, monitoring and legacy wells, integrity of the caprock or other sealing elements of the site, and be able to monitor the development and dynamic behavior of the CO2 plume. Additionally, an MMV plan must cover several monitoring ‘domains’ covering the geosphere of the injection zone and sealing layers, to the near surface hydrosphere, biosphere, and atmosphere. Loss of containment risk is a key element of MMV plans and is a site-specific issue. A Containment Risk Assessment (CRA) is an important part of the CO2 storage site selection process. The CRA identifies potential leak-paths and evaluates the likelihood and severity of any leakage. The basis of a CRA includes a multi-disciplinary analysis of the geological storage complex, incorporating legacy wells and future injector and monitor wells. All potential leak-paths, regardless of their perceived likelihood, are evaluated. A structured approach, utilizing the bowtie method, is recommended. Under this cross-discipline process, physical barriers which may prevent CO2 from leaving the storage complex, as well as mitigating measures that can either prevent and/or minimize the severity of any leakage, are mapped, and compiled into bowtie diagrams. Procedural barriers, which can include monitoring technology and/or implementation of corrective actions, further minimize the likelihood and/or severity of a specific leak and are added to the bowtie. By structuring the risk assessment around site-specific leak paths, project resources can be better optimized. Future work programmes can be focused on meaningful risk and uncertainty reduction while the project MMV plan can be focused on those leak paths which are considered to carry the greatest likelihood and severity. Monitoring technology selection is based on specific risks resulting in a cost-effective and proportionate MMV plan.

Many Alkanolamine (Amine) solvents such as Monoethanolamine and Methyldiethanolamine, which are used in the post-combustion carbon capture systems, are subject to chemical and non-chemical degradation. These solvents might react with impurities in the flue gas such as SOx, NOx and O2 that would lead to formation of different type of degradation products, or they might be thermally degraded with poor designed heat equipment within those systems. Gradual accumulation of these degradation products could lead to many operational problems in the carbon capture plant such as reduction of solvent absorption capacity, change of physical properties, increase of the solvent corrosivity, and change in the foaming tendencies. To avoid or minimize these operation challenges and many others, these solvents should be periodically or continuously purified in a solvent reclaimer unit. The suitable designed unit depends on the degradation products level, their accumulation rate, solvent capacity, and plant size. This work will discuss the topic in some details to help achieving successful carbon capture projects.

Modular multi-level converters (M2C) are a proven technology and have been widely used in the HVDC industry and for medium voltage drives for over 15 years now. When talking about High Power applications (anywhere from ~7MW to ~65MW), the traditional thought process is to start looking into Load Commutated Inverters / Synchronous motor from ~20MW and above. In the VSI (voltage source inverter) space, M2C drives technology has been very successfully executed up to 60MW – whether it be a Start-up duty or a Continuous duty application. Most customers perceive that moment you start going 20MW and above, you will have to deal with a massive complex Load commutated inverter (LCI) along with Power factor correction / Harmonic filters etc., that although reliable adds serious complexities at every level of execution and operations later. With M2C converters, Low voltage IGBTs and Capacitors are the basic building blocks – which are truly scalable to offer different output voltage levels right up to 13.8kV output (without the need for a step-up transformer). The cell-based, multilevel converter (M2C) offers an attractive solution for realizing Medium Voltage Drives as they offer several benefits such as: cell redundancy, scalability, low fault energy and easy cell exchange. These features, and more, put the M2C topology above the available topologies for MV inverters. Also, customer has the choice to opt for Air-Cooled drives right up to 65MW – eliminating the complexity to deal with aging Water-cooled drives. The simplicity and proven reliability / performance of M2C drive technology is worth evaluating for High power / high speed compressors and pumps.

Carbon Capture and Storage (CCS) is an essential technology to achieve volumetrically significant, near-term emissions reduction of energy systems and other hard-to-abate industries. Much focus is placed on subsurface suitability, as key technical risks and project economics are known to be strongly associated with reservoir characterization and selection. However, the importance of surface screening and stakeholder engagement should not be underestimated. In Alberta, the multi-step approval process for CCS hubs begins with identification of a large evaluation area. Through the Request for Full Project Proposals (RFPP) process, project proponents are granted the opportunity to explore across the evaluation permit area and obtain well data to quantify and qualify the subsurface storage volume. This subsurface de-risking process and the subsequent monitoring, measurement and verification (MMV) principles to evaluate sequestration performance are defined by the government who ultimately determines subsurface feasibility and grants carbon sequestration tenure. In contrast, surface screening to identify appropriate sites for positioning the facilities and infrastructure needed to support CCS are largely left to the project proponent to negotiate with local landowners, Indigenous communities, and other potentially impacted stakeholders. Surface screening is critical for determining optimal flowline and pipeline routes, positioning of compressor stations, as well as the siting of injection and MMV wells. Non-ideal placement of any or all of these components can significantly increase both CAPEX and OPEX costs. Project delays and resulting cost escalation can be triggered by possible environmental impact assessments and cumulative effects considerations. Additionally, responding to public apprehension regarding alleged social and environmental impacts could require a significant commitment to public education and outreach. A case study of the Navigator CO2 Ventures’ Heartland Greenway project in the US Midwest will demonstrate the importance of upfront surface screening and ultimate surface sites selection to overall CCS project success. There are many similarities between Heartland Greenway and numerous proposed Alberta CCS projects. Several important components of this notable CCS project were in place. Industrial emitters were interested in decarbonization opportunities and were willing to commit emissions volumes to the project. A known and tested sequestration reservoir target was identified and the pore space was available for project use. BlackRock and others had invested in the project. US Government incentives were available to improve project economics. Regardless of these significant milestones, in October 2023, Navigator withdrew their sequestration permit application and subsequently cancelled their pipeline project. This presentation will review the importance of surface screening and stakeholder engagement in CCS project design. The link between these proactive activities and project risk mitigation, economic viability, and community and Indigenous acceptance will be discussed in an effort to improve future CCS project outcomes.

Carbon Capture & Storage is rapidly scaling in North America and worldwide to help meet global goals for reduction in CO2 emissions. Every CCS project requires the operator’s commitment to monitor, measure and verify (MMV) the injected subsurface volume of CO2. In general, monitoring and detection should provide information as close to the injection reservoir as possible to identify any unexpected behaviour as early as possible. Effective and strategic use of subsurface technologies is needed to minimize operating costs. Various methods have been proposed for monitoring CO2 plume containment and conformation both from the surface and within the wellbore. However, not all technologies will work for all types of reservoirs and care must be taken to ensure the right technologies are deployed. Additionally, prior to finalizing the location of injection and monitoring wells, a full understanding of the subsurface is required to identify any potential leakage issues such as faults or variations in reservoir properties. This can be accomplished by acquiring different types of baseline measurements such as passive and active seismic which can help establish the pre-injection, base-line subsurface interpretation. In this talk we will focus on passive, borehole, and surface seismic technologies;examining how these technologies can be deployed both for baseline measurements and in a staged investigation approach to enable accurate, yet cost-effective ongoing monitoring. Examples from microseismic and vertical seismic profiling (VSP) studies will be shared along with methods for optimizing baseline measurement programs such conventional 3D or alternative surface seismic. Methods that can provide both accurate 3D subsurface images as well as reduce the overall surface footprint (and cost) of these MMV programs will be reviewed including results from the recent award-winning EcoSeis™ project (winner of the 2024 Global Energy Show Collaborative Trendsetter award). This project has shown that it is possible to safely and efficiently acquire baseline seismic with up to a 50% reduction in environmental impact while achieving the same high-resolution subsurface image. Results from the project will be shared including new learnings for cost effective, environmentally sustainable, 4D timelapse seismic. Additionally, the talk will provide an overview of the upcoming Carbon Capture Collaboration Project, which will evaluate various technologies by gathering datasets simultaneously and comparing them in various combinations to identify the most efficient and effective approach for CCS measurement, monitoring, and verification.

In 2022, I presented at the Knowledge Bar about the importance of effective public and stakeholder engagement for CCS projects. At that time, the numbers of CCS projects in development had not yet escalated as they have in Alberta and Saskatchewan – indeed to other parts of Canada like Manitoba, BC and Ontario. What challenges have this increase in planned projects caused in terms of public outreach and communications? Some project have multiple players, with hub managers offering several CO2 suppliers injection locations. The technical challenges, alone, from large projects injecting close to each other raises different risk concerns from communities that must be addressed. This presentation will look at the evolution of CCS communications – both internal to projects and external to variable audiences. Recent criticisms of CCS by media outlets – often pointedly against the whole idea of it as an emissions reduction strategy – has been exacerbated by events like the recent safety failure at the Denbury CO2 pipeline in Sartartia Mississippi. What have we learned about public communications challenges in the past three years as CCS has geared up in both the US and Canada? This presentation will look at some of the new CCS outreach challenges, how to address them, and when is a project conceivable or acceptable to a community, and when is it not.

COMPRESSED AIR SYSTEMS 101 • Introductions & Wiseworth Ingersoll Rand info • Considerations for Instrument Air Requirements (overview) • Air Compressor Choices & Controls • Control (wet) Air Receiver Selection • Air Dryer Selection and Considerations • Filtration Selection and Considerations • Dry Air Receiver Selection This is a very fundamental presentation which serves as a good refresher for senior technical personnel and as a good start for junior technical positions. While it is a fundamental presentation there is still an allowance for technical questions.

In the journey towards sustainable carbon capture, invaluable lessons gleaned from conventional sites illuminate the path towards robust corrosion, integrity, and sustainability management. This paper embarks on a journey to explore the symbiotic relationship between these lessons and the imperatives of carbon capture operations. By dissecting the three primary challenges—efficiency, externality, and circularity—within the context of both conventional and carbon capture sites, it elucidates actionable solutions poised to drive long-term efficiency and sustainability in carbon capture endeavors. Central to this discourse are the foundational concepts of designing for purpose, maintaining integrity throughout the lifecycle, and decommissioning with a strategic focus on second-life utilization. These principles, honed through decades of experience in conventional industries, stand as testament to their applicability and relevance in the realm of carbon capture. By embracing and integrating these principles into carbon capture projects, organizations can circumvent pitfalls, mitigate risks, and foster a culture of sustainability. Moreover, the paper issues a clarion call to eschew the repetition of past mistakes, urging stakeholders to glean wisdom from the annals of history. The cost of repeating errors, as evidenced by catastrophic incidents and staggering economic repercussions, underscores the imperative of learning from, rather than perpetuating, missteps. Harnessing the collective wisdom of conventional sites offers a beacon of hope—a roadmap towards a future where carbon capture projects thrive in harmony with environmental stewardship. In essence, this paper serves as a catalyst for change, advocating for a paradigm shift in the approach to corrosion, integrity, and sustainability management in carbon capture. It underscores the imperative of embracing past lessons, seizing opportunities for innovation, and forging a path towards a more resilient and sustainable future. Keywords: Carbon Capture, Conventional Sites, Lessons Learned, Corrosion Management, Integrity, Sustainability, Efficiency, Circular Economy, Second-life Utilization.

In today's rapidly evolving energy landscape, the integration of AI/ML and digital twin technologies has become imperative for the sector's sustainable growth and efficiency, extending to innovations in carbon capture, utilization, and storage (CCUS) processes. Physic based Digital twin technology, integrating high fidelity 3D physics-based simulations combined with machine learning (ML) analytics, offers a transformative approach in real-time systems analysis, facilitating predictive maintenance scheduling and performance optimization. At the core digital twin technology lies the integration of physics-based simulations with real-time data from physical assets, enabling a virtual replica of the system's behavior. This presentation explores the intersection of energy industry with simulation-based digital twin technology, emphasizing the pivotal role of AI/ML in shaping energy industry’s future and helping it in achieving the net-zero goals. The presentation delves into the utilization of simulation-based digital twins in optimizing of an example of CCUS process to illustrate the transformative potential of such technology in this field. In the context of CCUS, physics-based digital twin entails capturing the intricate fluid dynamics within capture units, utilization reactors, and storage reservoirs through CFD simulations. By modeling multiphase flow, reaction kinetics, digital twins provide insights into system behavior and facilitate optimization of CCUS efficiency. It can also include FEA analysis to assess the structural integrity and durability of CCUS infrastructure, such as storage vessels and pipelines. The workflow encompasses compressing detailed 3D models into lightweight Reduced Order Models (ROM) that extends the digital twin's utility, allowing seamless integration into system-level models including raw sensors data, engineering knowledge, in house codes, 0D 1D libraries, which can be hosted on IoT platforms. These enhanced twins, not only offer insights into equipment performance and risk management beyond raw data but also empower field personnel to understand failure root causes, thus optimizing operations, maintenance, and reducing downtime by physics-based decision-making. Application of a validated 3D ROM of carbon capture unit and its accuracy compared with high fidelity CFD simulation will be available to audience during the conference presentation. Also, the connection of 3D ROM to the absorption-based carbon capture top-down system level digital twin will provide a holistic view of such technologies. System architecture includes various components including absorbers, desorbers, pumps, compressors, heat exchangers, and piping, each characterized by relevant curves or equations to capture their physics. Finally, this presentation exploring other applications in the energy sectors will clarify the architecture of digital twins facilitated by Hybrid Analytics capability of Ansys. This provides insight into how hybrid digital twins can improve the efficiency, reliability through informed decision-making in the design and by optimization of system performance while minimizing energy consumption and operational costs.

This presentation reviews our experience with a recent lawsuit regarding subsurface migration of an acid gas plume (roughly 2/3 CO2, 1/3 H2S). In this case, plume migration outside of an operator's predictions, based on an over-simplified geologic model, ultimately led to tens of millions of dollars in damages awarded to the plaintiff in the case. We will begin with an overview of the specifics of the case that are now publicly available (e.g. location, geology, development history). We will describe the modeling work undertaken by the various parties, and illustrate the pitfalls associated with some of the modeling choices taken by the defendant – but also discuss some of the potential incentives to simplify modeling and describe cases where it may be appropriate. We will conclude with the ultimate financial consequences and draw key takeaways that are applicable to the broader CCS industry as it scales up.

Moving towards a sustainable future entails navigating new territories, necessitating systematic planning, meticulous evaluations, and innovative approaches. In the realm of carbon capture and storage (CCS), assessing subsurface storage and containment is vital to meet three fundamental requirements: capacity, injectivity, and containment. Risks such as CO2 leakage, induced seismicity, and related environmental, health and safety concerns emphasize the need for rigorous evaluation methodologies. Our evaluation workflow aligns with and incorporates principles from the CSA Z741 standard for Geological Storage of Carbon Dioxide, ISO 27914 standard for Carbon Dioxide Capture, Transportation and Geological storage and the US Department of Energy NRAP Recommended Practices for Containment Assurance and Leakage Risk. This structured approach comprises five phases: Geological Studies (Site Screening & Selection), In-situ Reservoir Testing, Site Characterization, Containment Studies, and Computer Modelling. During site screening and selection, prospective sites are identified and evaluated to determine the most promising candidates for further assessment. It incorporates geological evaluation, land use considerations, analysis of existing data, and basic geomodelling. Subsequently, in-situ reservoir tests offer valuable insights into formation permeability, continuity, boundaries and connectivity. Site characterization entails analysis of the geology, geochemistry, and geomechanics of the storage formation and the caprocks, as well as any existing wells. Further containment studies, including in-situ testing or geotechnical lab testing, are essential to assess seal integrity and migration pathways. As part of a comprehensive site characterization, various models are developed to simulate different aspects of the subsurface system. These include geological static models, reservoir models, geochemical models, and geomechanical models. The models will rely on actual test data as inputs to reduce uncertainty and are designed to predict CO2 movement, assess containment integrity, and evaluate potential risks such as induced seismicity. The workflow is iterative, continuously refined with new data to ensure long-term containment and safety. By incorporating robust evaluation methodologies, this workflow contributes to the success and sustainability of CCS initiatives, facilitating the transition to a low-carbon future.

The North American energy industry has made strides in capturing CO2 from relatively pure streams, yet the daunting challenge that looms large is extracting CO2 from combustion sources—a task that is both critical and complex. This presentation zeroes in on this emerging challenge, particularly addressing midstream operators who navigate a broad landscape of opportunities in compression engines. Through a methodical evaluation, CANUSA EPC scrutinizes three different flow rates in an existing compressor station design, employing the widely used Caterpillar engines as a standard. The study delves deep into solvent amine systems, celebrated for their proven compatibility with these engines, anchoring the analysis in practical, real-world scenarios. The eye-opening findings of the analysis show that achieving the capture and compression of CO2 for offtake necessitates a pricing of $164 per ton (USD). However, juxtaposed against current market forecasts, which do not anticipate CO2 pricing to hit this mark until post-2030, questions about the immediate viability of such projects come to the fore. We discuss processing, deployment considerations, and a nuanced showcase of how technology influences cost. This presentation sheds light on the intricate economics of CO2 capture, especially from compressor station engine exhaust, highlighting the influence of factors like CO2 pricing, net CO2 captured, and existing infrastructure on the feasibility of these initiatives.

As many operators explore the potential to capture, sequester, and utilize CO2 from their facilities, some are realizing the complexity of developing those projects from a technical, economic, execution, and permitting perspective. This presentation will focus on the process steps typically required from the moment of CO2 generation to its eventual sequestration or utilization, including challenges, solutions, and industrial project experience. Axens has a full range of CO2 solutions including CO2 capture, dehydration, purification, DeNOx, and DeOx, which can be deployed in pre and post-combustion scenarios. Additionally, as operators explore syngas utilization opportunities, we will explore the various processing options to purify syngas for use in Fischer-Tropsch or other conversion technologies. We will also share updates after ~2 years of operation at our post-combustion CO2 capture demonstration plant located in Dunkirk, France.