Making CCS Investable: Insights from Real Projects Across Power, Waste and Industry

Sponsored by:

Shell Catalysts & Technologies and Technip Energies have supported numerous projects worldwide – from power and cement to energy-from-waste and refining. Many of these are now progressing through FEED, FID or into execution. The two organisations have established a global exclusive alliance to support carbon capture projects, combining Shell’s CANSOLV* CO₂ Capture System with Technip Energies’ expertise in project design and execution. Drawing on real projects such as SaskPower Boundary Dam (Canada), Calpine Baytown (USA), and Net Zero Teesside Power and Viridor Runcorn (UK), this session will explore how industrial CCS projects are being de-risked and delivered. It will highlight the integration, design and operating challenges that matter most to investment decisions and show how alliance-based delivery models are helping to make CCS projects viable, investable and operationally robust.

Open Access Wabamun Carbon Hub Development Journey

Sponsored by:

Open Access Wabamun Carbon Hub is being developed by Enbridge, north and west of Edmonton, to provide CO₂ transportation and storage solutions, helping to decarbonize large industrial emitters near the Alberta Industrial Heartland. Since securing evaluation rights, Enbridge has conducted multiple activities to derisk the subsurface, which included drilling and testing two wells, acquiring large-scale 3D seismic data, analyzing core samples, as well as planning MMV, and undertaking pipeline and other surface development work. This presentation will provide an update on development progress and pore space evaluation activities. It will also share valuable insights and lessons learned from the journey toward commercializing this large-scale carbon sequestration hub, addressing both technical and non-technical aspects.

Presentation by Pathways Alliance

Sponsored by:

To be Announced

Presentation by Baker Hughes

Sponsored by:

To be Announced

Learnings from a Decade of Operations at SaskPower

Sponsored by:

The Canadian power generator SaskPower has operated a 1 Mt/y post-combustion carbon capture facility for over 10 years, using Shell’s CANSOLV CO₂ Capture System with ongoing support from Shell Catalysts & Technologies. Boundary Dam 3 (BD3) pioneered post-combustion carbon capture and storage and overcame early first-of-a-kind challenges, reshaping global understanding of CCS. In this session, experts will share key operational insights and learnings that enabled them to deliver the BD3 CCS project and prove that carbon capture can be deployed at scale, even in the most demanding conditions. Reflecting on the progression of the CCS industry over ten years and its future direction, this session will also explore how deep expertise, commercially effective solutions, trusted technology and commitment to successful outcomes are key to making carbon capture investable.

Induced Seismicity Requirements for Fluid Disposal in Alberta

Sponsored by:

The Alberta Energy Regulator (AER) is responsible for fluid disposal activities through out the life cycle of a fluid disposal operations. The current induced seismicity requirements outline in AER’s Directive 065: Resources Applications for Oil and Gas Reservoirs applies to all disposal fluid classes described in Directive 051: Injection and Disposal Wells – Well Classifications, Completions, Logging, and Testing Requirements. The presentation will provide an overview of the requirements pertaining to the following: • Applying for a new fluid disposal well. • Amending the operating conditions of an existing fluid disposal well. • When an existing disposal well is linked to a seismic event. • Monitoring, mitigation, and response plan.

Presentation by Pathways Alliance

Sponsored by:

To be Announced

Presentation by Baker Hughes

Sponsored by:

To be Announced

Leveraging CCS to Generate New Revenue Streams & Decarbonize an Industry

Svante’s technology is targeted to industrial decarbonization including oil & gas, hydrogen, pulp & paper, lime, cement, steel, petrochemicals, and more. Svante’s filters are applicable to both direct air capture (DAC) and point source industrial carbon dioxide capture applications. DAC and point source however use different adsorbent materials. The pulp and paper industry stands out among industrial sectors for its established use of waste biomass to power mill operations. This existing reliance on renewable energy sources positions pulp and paper mills as promising candidates for achieving negative emissions by integrating carbon capture and storage (CCS) technologies alongside biomass utilization. To target this opportunity, Svante has developed a Rapid Cycle Temperature Swing Adsorption (RC-TSA) process using structured solid sorbents as an alternative to traditional technologies. This study focuses on scaling up the CALF-20 Metal-Organic Framework (MOF) sorbent process for pulp and paper flue gas which demonstrates high resistance to steam, oxygen, and acidic gas contaminants such as NOₓ and SOₓ—making it particularly well-suited for pulp and paper flue gas applications. In addition, the use of low-grade energy sources (such as inlet flue gas, product CO2 cooling, and CO2 compressor trains) which is a unique feature that allows energy that would typically be considered a “waste product” and rejected to cooling system to be re-used for the regeneration step of the process and reduces the overall energy requirement for the system. The use of low temperature/waste heat for carbon capture operations provides heat integration opportunities with the mill to minimize the use of any fossil fuels and maximize the use of clean electricity. These integrations result in significant improvements in efficiency and lower emissions making it a great candidate for efficient and affordable carbon dioxide removal (CDR) from point-source capture carbon emissions. This presentation will present an overview of an integrated Svante carbon capture plant with a pulp mill and techno-economic assessment leveraging new revenue opportunity from biogenic CDR credits.

Qualitative & Quantitative Risk Assessment supporting MMV Planning & Monitoring Solution

Presentation by Pathways Alliance

Sponsored by:

To be Announced

Carrots, Sticks & Carbon: A Comparative Economic Case Study of Carbon Transport & Storage

GLJ will deliver a comprehensive update on the current status of policies and incentives supporting the economics for Carbon Capture and Storage (CCS) deployment in Canada and in the United States (U.S.). Key components of the presentation will include an analysis of the incentives in each jurisdiction; deterministic economic modelling of a theoretical CCS project based on public data analogs; scenario analysis of the project economics based on different assumptions of incentives eligibility; and the application of stochastic modelling techniques to assess the impact of project cost uncertainties under the varying scenarios of incentive eligibility. The analysis will begin with a description of relevant CCS policies and incentives in both Canada and the U.S. as to contextualize the functionality and potential economic impact of each. Canadian policies and incentives that will be described and subsequently considered for inputs into project economic modelling scenarios include: 1) Alberta Technology Innovation and Emissions Reduction (TIER) Carbon Pricing 2) Federal CCUS Investment Tax Credit (CCUS-ITC) 3) Alberta Carbon Capture Incentive Program (ACCIP) 4) Carbon Contracts for Difference (CCfD) U.S. policies and incentives that will be described and subsequently considered for inputs into project economic modelling scenarios include: 1) Inflation Reduction Act Section 45Q Carbon Capture Tax Credits (45Q Credits) 2) California Low Carbon Fuel Standard Credits (LCFS Credits) Voluntary carbon market credits and Carbon Dioxide Removal Credits (CDRs) will also be discussed in the context of each jurisdiction. Following the description of relevant policies and incentives, a deterministic cash flow model will be presented. The economic model will be based on a hypothetical CCS project that will inject at a flat rate of 1.0 million tons per annum (MTPA) into a saline aquifer at approximately 2,000 meters depth over an assumed operational project life of 25 years. Real-world cost estimates will be derived from public data. The physical scope of the model will encompass the development and operation of the CO2 Transportation and Storage (T&S) infrastructure only, as to run the economics from the perspective of an open-access CO2 T&S Hub Operator. The model will then apply ranges of uncertainty to median project cost estimates through stochastic modelling techniques. Stochastic modelling integrates probabilistic distributions for key input variables, such as CAPEX, OPEX, service fees and funding eligibility. This methodology generates a spectrum of potential economic outcomes across a range of logically distributed input parameters, providing a comprehensive understanding of economic possibilities associated with the CCS project scope as described above. Both the deterministic and stochastic models will be run under different scenarios of policy and incentives eligibility in both Canada and the U.S., thus comparing the economic performance of the CCS Hub across multiple jurisdictionally specific scenarios.

Leading The Way on Low Carbon Power - Entropy iCCS TurbineTM

Entropy is building a first-of-kind clean power CCS project, planned to come online mid-2026. The Glacier Phase 2 CCS project includes carbon capture on a natural gas fired turbine, resultng in low-carbon intensity electricity that will be used on-site and supplied to Alberta’s power grid. Entropy is a full-scope developer of commercial scale CCS projects – providing technology, expertise and capital. Entropy built a first-of-kind post-combustion CCS project at the Glacier gas plant in Saddle Hills County (in north-west Alberta, 99km from Grande Prairie) in 2022 and 2023. The Glacier CCS Phase 2 project, to decarbonize the remainder of emissions at the facility will result in both low-carbon baseload electricity and low-carbon natural gas. These low-carbon solutions through CCS, low-carbon natural gas and low-carbon power provide a path across a variety of industries to provide emissions reductions pathways to meet both regulatory and corporate objectives.

Dense Phase CO2 Pipelines – Design Considerations

The design of dense phase CO2 pipelines represents some unique challenges and unknowns. Since there are relatively few of these pipelines in design, construction, or operation, this presentation will help to highlight some of these specific challenges and provide pipeline designers with a guideline. These topics will all be discussed in a technical matter with direct reference to codes, specifications, and industry best practices. Water and Carbonic Acid CO2 + water + pressure = carbonic acid. Carbonic acid is extremely corrosive to carbon steel. With proper process design and drying, this risk can be mitigated. Metallurgy and Welding This is biggest concern for design. The industry standard is carbon steel. Existing projects have selected high grade steels due to the high pressure, presence of contaminants (NOx/SOx), and unknown effects of the service fluid. The metallurgy and welding procedures will be specialized. Design Temperature For many applications, the source of the CO2 is exhaust from fossil fuels. This could lead to high design temperatures. Pipeline coatings are very sensitive to high temperatures. During a blowdown the dense phase CO2 will flash causing the JT Effect. This could lead to cryogenic conditions. Planned blowdowns must be able to accommodate reasonable temperature drops. Hydraulics – Steady State and Transient The critical point for dense phase CO2 is ~7MPa. Adding a buffer to avoid any flashing and considering transient hydraulic spikes, the design pressure will exceed an ANSI 600 rating (9.93 MPa). If a midline pumping station is unavailable the required design pressure could exceed the ANSI 900 rating (14.9 MPa). This will lead to many extra costs including thicker line pipe and higher rated flanges and valves. The actual fluid behaviour of dense phase CO2 is still relatively unknown. Because it is a critical fluid and not an incompressible fluid (e.g. water), the transient hydraulic characteristics may be overstated. Stress Due to thick line pipe, low and high design temperatures, and the possibility of transient hydraulic spikes the stress design for dense phase CO2 pipelines can be complicated. There will likely be considerable thermal growth in the stress model. There could be water hammer at the bottom of hills. This will lead to high stress at bends and other features.

Closing the Data Gap: De-risking Economics and Ensuring Safe Long-Term Carbon Storage

Carbon capture and storage (CCS) is increasingly seen as a critical pathway to achieving net-zero targets—but the success of this strategy hinges on the reliability of the data from the subsurface evaluation. While the concept of injecting CO₂ into geological reservoirs may be familiar to those in the oil and gas sector, derisking investments and ensuring safe long-term storage will require a fundamental shift in how data is acquired, assessed, and evaluated. Some CCS projects have built their economic models and feasibility assessments around a "minimum requirement" approach - relying on limited data and assumptions that may fall short of addressing the full spectrum of economic and safety risks associated with CO₂ storage. This presentation highlights the critical data gaps in geologic carbon storage and makes the case for a more rigorous, site-specific approach to data acquisition and testing. Key uncertainties include: • Storage capacity and injectivity of the reservoir, • Long-term integrity of caprocks, • Risks of induced seismicity due to pressure buildup, • Potential for CO₂ migration through faults, fractures, or legacy wells. The implications of these data gaps are substantial. A project that appears viable on paper may ultimately prove uneconomical. In more serious cases, a failure in containment could undermine the climate benefits of CCS, cause environmental harm, and diminish public and regulatory trust—resulting in costly delays, reputational damage, and setbacks to the broader adoption of carbon storage technologies. To address these challenges, this presentation advocates for a paradigm shift in subsurface evaluation practices. This includes comprehensive baseline reservoir characterization and geomechanical testing tailored specifically for CO₂ storage. By prioritizing high-quality, complete data from the outset, project developers, regulators, and stakeholders can build the confidence needed to advance CCS responsibly and at scale.

Lessons Learned from BASF OASE® blue Technology Operations

Solvay/SIAD in Italy has been operating a carbon capture plant removing CO2 from flue gas streams since 2018. The plant was designed and constructed by TPI and utilizes BASF's OASE® blue technology which was initially designed for MEA solvent system. The plant captures approximately 120 metric tons of CO2 per day for chemical utilization purpose and simultaneously supplying liquefied CO2 to external customers in the region. The flue gas stream originated from two major sources: a low-pressure off-gas stream from bicarbonate production and flue gas from lime kiln and coal combustion. Since startup of the unit, there have been various challenges following the decision to switch from MEA solvent system to OASE® blue technology. Key challenges observed in the unit were particulate and SO2 carryovers, high CO2 concentration in the feed gas, and solvent health management. To address and optimize these issues, countermeasures include improvement of pretreatment unit line up and adjustment of operational strategy to improve carbon capture performance. Additionally, the installation of an ion-exchange unit has proven to reduce HSS levels in the solvent effectively, decreasing the solvent make up rate into the unit. This achievement is outstanding as OASE blue solvent continues to perform exceptionally well in achieving the desired removal rate and producing a high purity CO2 product, even when operating with a heavily contaminated flue gas sources. Despite initial setbacks, the plant has demonstrated the economic viability and transformative potential of BASF's OASE blue technology. The collaborative efforts of BASF, TPI, and SIAD/Solvay have been crucial in ensuring the long-term robustness and reliability of the plant highlighting a valuable lesson learned.

Carbon Circle: Modular, Open-source CCS Solutions Built on Norwegian Expertise

Initiated by the introduction of CO₂ tax on the Norwegian continental shelf in 1991, Norway has built one of the world’s most robust and practical foundations for CCS. This long-standing legacy includes pioneering projects such as the Sleipner CO₂ storage project (1996), Technology Centre Mongstad (2012) and Longship (2025), which have contributed to unique operational insights and technology validation at scale. The experts of Carbon Circle build on hand-on experience of this heritage to offer advanced post-combustion carbon capture solutions, combining Norwegian process expertise with full EPC capabilities. Carbon Circle’s CCS technology platform is based on CESAR1, a high-performance, open-source amine solvent developed through EU collaboration and extensively investigated and verified at numerous sites, including TCM. By leveraging CESAR1, we provide clients with a transparent, flexible, and non-proprietary solution that ensures operational reliability without licensing constraints. Carbon Circle delivers pre-engineered, modular capture plants designed for rapid deployment, cost efficiency, and ease of integration into existing industrial sites. With a clear focus on practical implementation, scalability, and technology openness, Carbon Circle is committed to accelerating the deployment of CCS across hard-to-abate sectors.

CO2TruTM – A Breakthrough in Post Combustion Carbon Capture

PECL/PRSB has confidence with the findings and would like to share the learnings from operating the four technologies that were tested on actual natural gas engine post-combustion exhaust. The findings may help the industry with gaining traction in advancing carbon capture and storage in Canada.

To be Announced

Updated for MHI KM CDR Process™

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). Eighteen (18) commercial plants with CO2 capacities ranging from 0.3 to 4,776 tons per day have been delivered around the world as of March 2025. 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 KEPCO / MHI pilot plant and Technology Centre Mongstad (TCM), Norway in 2021. ExxonMobil and MHI have entered a CO2 capture technology partnership in 2022. Leveraging the strengths of both companies to meet customer needs, MHI and ExxonMobil will provide each strength in CO2 capture technology and CO2 transportation/storage, respectively. In addition, both works together to develop next generation amine solvent technology for CO2 capture. This joint effort will ensure that 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 and CO2 capture cost through further development of proprietary solvent and optimization of process system. Below are the recent notable updates: 1. Conducted pilot tests on various facilities such as biomass, waste, gas engines, ships, cement plants, blast furnace, wood pellet plants, paper mills. 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, FPSO, ships, CCGT and others. These integration studies include optimization of the heat recovery system between host unit and CO2 capture, and flue gas impurity removal treatment. A closer study of a heat pump using low-temperature waste heat sources both inside and outside the CO2 capture plant was also conducted. 3. A CAPEX reduction study was carried out for the CO2 capture unit, which accounts for a large cost in a CCS project. This includes a wide range of efforts such as standardization of the unit, modularization to reduce direct and indirect costs for on-site construction, adoption of advanced equipment and others. 4. A CO2 capture pilot plant with a capacity at approximately 5 tons/day was installed and started operation at Himeji No.2 power plant of KEPCO in Japan. The new plant accelerates and demonstrate activities towards next generation CO2 capture technology under the agreement with ExxonMobil, as a substitution of the previous pilot plant installed at Nanko power station in 1991. This presentation focuses on providing an update of Advanced KM CDR process(TM) including the various MHI activities mentioned above.

Presentation by Geofirma

To be Announced

Carbon Capture 101

Are you working on a Carbon Capture Project and a non-Process Engineer, a Student or a non-technical person hearing all about Carbon Capture, Pre/Post Combustion, Amine/Solvent, Cryogenic and Solid Media Based and you are wondering what they are talking about? This presentation will cover what is carbon capture, what is the difference between pre and post combustion carbon capture with examples, high level comparison of different technologies.

Partnership with Suncor and Cenovus for Enhancing the Efficiency of the Amine Process

One of the key challenges hindering the widespread adoption of Carbon Capture, Utilization, and Storage (CCUS) technologies is the energy intensity and associated cost of commercially available carbon capture processes. To tackle this issue, InnoTech Alberta, in collaboration with Suncor and Cenovus, is pursuing improvements to incumbent amine processes, which have the potential to lower energy requirements, operational costs, and carbon emissions. InnoTech Alberta operates a six-tonne-per-day amine-based CO2 capture unit at the Alberta Carbon Conversion Technology Centre (ACCTC) using flue gas from the Shepard Energy Centre. During the NRG COSIA Carbon XPPRIZE competition, InnoTech Alberta successfully operated the unit using mono-ethanolamine (MEA) as the solvent. However, two significant challenges related to amine-based processes emerged: the high energy demand for solvent regeneration and the issue of solvent degradation, both of which present opportunities for improvement. The Amine Intensification Process (AIP) project addresses these challenges by - validating key enhancements to the existing and proven amine-based CO2 capture method. It incorporates three significant improvements to the conventional amine process, collectively targeting a substantial reduction in carbon capture energy intensity and operational costs: 1. High-Efficiency Packing (Absorption Tower): The introduction of high-efficiency mass transfer materials and packing design contributes to a decrease in capital costs associated with the construction of the capture unit. 2. Water Lean Solvent (WLS): In a typical amine-based process, capturing CO2 requires considerable energy consumption, typically ranging from 3.2 to 4 GJ per tonne of captured CO2. With the proposed WLS solvent, based on existing laboratory data analyses and estimates, the regeneration of the WLS is projected to require only 2 GJ per tonne of CO2, a significant reduction in carbon footprint and energy costs when compared to typical amine-based processes. 3. Microwave Regeneration System (Stripper Tower): Laboratory results indicate that microwave heating is more energy-efficient than the commonly used direct conductive heating. By utilizing this microwave technology in conjunction with WLS, the energy demand for capturing CO2 can be reduced to 1.4 GJ per tonne of CO2 captured.

Is Canada North America's Premier Region for CDR?

With recent changes in the political environment of the US, the reality of a burgeoning CDR market has been called into question. Since the change in administration, we have seen climate change-focused laws and regulations targeted for repeal, a refocus on traditional energy sources, and large swaths of CCUS funding, including DOE funding for key DAC projects, come under risk of cancellation. This leaves the key question: could Canada attract large-scale CDR projects to the north as interest in the US wanes? Our Research will answer this question through the evaluation of the political environment, changing market dynamics, project costs, and access to key industries. Rystad Energy’s research will begin by delving into the changing political landscape on both sides of the border, covering recently announced changes to incentive programs, regulatory frameworks, and the future viability of a CDR market. We will then investigate planned BECCS and DAC projects at a regional level, the scale of these developments, and progress towards operational start. Using several projects as case studies, we will evaluate the pros and cons of investment in each country. A focus will be placed on the availability of key project inputs, including biogenic carbon dioxide emissions, government funding and incentives, and their impact on the overall cost of capture, access to healthy carbon credit markets, and the availability of low-cost non-emitting power sources. Using Rystad Energy’s emissions tracking and risking tools we will model access to biogenic emissions for use in BECCS projects in key development regions in each country. This information will inform conclusions around the potential scale of BECCS development in each country. Using our in-house power sector research, we will provide details on the availability of low-carbon power sources required for the successful development of BECCS and DAC projects. This will include evaluations of the excess power capacity available today, potential for further development, and the cost of these resources. Using our levelized cost of capture and levelized cost of DAC tools, we will evaluate the impact of current incentives on the total cost of CDR project delivery, highlighting the regions in which projects should be expected to be most profitable as well as break-even prices required from credit sales. Using our coverage of CDR contracts and credit sales, we will provide an update on whether required breakeven prices are realistic in each key region. The outcomes of this analysis will inform a project risk scorecard, which will be used to support our belief that Canada will provide a superior investment environment for CRD projects as the carbon removal market continues to develop.