THURSDAY 20 NOVEMBER 2025
We will have 6 high quality presentations throughout the day.
** Please note that the schedule is subject to change - details are being updated on an ongoing basis, so please check back regularly for the latest status **
Session 1: Application of Generic MEA for CO2 Capture of Direct Exhaust Emission from Aluminium Smelting
Speaker: Martin Curtis, Bechtel Ltd.
Authors: Martin Curtis and Caroline Metcalf, Bechtel Ltd
Abstract: The paper explains the application of Carbon Capture to the direct atmospheric exhaust emissions from an Aluminium Smelter. In Europe over 97% of the power consumption for electrolysis (used in the smelting process) is from hydro-electric power and other renewables, so the direct exhaust emissions from smelting is the focus for decarbonisation. The CO2 content in the exhaust gas can be as low as 1%v and has led to consideration of other options to amine-based carbon capture, which is typically applied for CO2 concentrations down to 4%v for natural gas turbines. Generic MEA based absorption will be shown to be successfully applied to obtain 90% capture to this exhaust stream by addressing the constraints imposed by the low CO2 partial pressure, the large gas volumes and a typical smelter layout.
The paper explains the further challenges to be addressed in the carbon capture plant design and for further investigation by pilot plant operation, such as impurities in the exhaust gas.
Session 2: First Greenfield Cryo-HRU LNG Plant Up and Running
Speaker: Wabe Bakker, Shell Project & Technology Group
Authors: Shell and BASF
Abstract: The challenges of processing lean feed gas to produce LNG using standard plant designs are well known. Many existing LNG plants, which were designed with a traditional LNG pre-treatment line-up relying on vapor liquid separation to remove heavy hydrocarbons (HHCs), struggle with HHC freezing in the cold section of the plant. With these challenges known, Shell took a new and innovative approach to LNG plant design by implementing Durasorb LNG MAX adsorptive HHC and water removal in the pre-treatment section of the plant. Following Shell’s qualification of Durasorb in 2020, plant design commenced and this greenfield LNG plant, DLNG, started up in April of 2024.
Shell selected Durasorb LNG MAX at the conception of the DLNG plant because the grid gas processed is expected to contain a heavy tail. With this technology in place, other unique design features were also implemented to ensure world-class operation and consistent LNG production. These features include continuous or online monitoring of water and HHC concentrations in feed and treated, condensate (water and HHC) handling.
In this paper, Shell and BASF will jointly discuss the technology selection, plant design, plant operation, including the unique features of the plant, and performance to date. Utilization of Durasorb LNG MAX technology ensures removal of HHCs under a wider design envelop, which has already proven important due to the feed gas source switching from lean Russian gas at the onset of plant design to heavier Norwegian gas at start up. This flexibility allows for consistent plant operation and performance. To date, the DLNG plant has been delivering on spec gas and does not shut down or reduce LNG production due to HHC freezing. This approach to a greenfield LNG plant provides a roadmap for other LNG projects on how to avoid well known challenges using new and innovative approaches to plant design.
Session 3: Optimizing Green Ammonia Operation in Intermittent Mode
Speaker: Reginaldo Marinho, Rely Solutions
Author: Jonathan Girault, Rely Solutions
Abstract: Proper intermittency management in green ammonia production is a key performance driver of the whole production plant. The main challenge is to manage two units: the hydrogen production by water electrolysis which is very flexible and reactive together with the ammonia synthesis which is more sensitive to fluctuation.
Attention is often focused on maximizing hydrogen production by trying to follow as close as possible the available power, and by using hydrogen storage to keep a constant Ammonia production. This simplistic approach usually leads to a higher Levelized Cost of Hydrogen (due to high storage cost) and safety issues (due to high pressure hydrogen).
Rely has completed a case study based on very large ammonia production project (> 1GW electrolyser installed capacity) , proposing to our client the best plant operation.
This paper describes the results of this study.
Session 4: Novel Column Internal That Unlock Existing Gas Treating Units' Potential
Speaker: Ton Schlief, Shell Global Solutions
Authors: Anh Do Thi Viet and Gary Wang, Shell Turbo Technologies
Abstract: In recent years, the oil and gas industry has faced increasingly complex challenges, including handling more contaminated resources, adhering to stricter product specifications, maximizing asset efficiency, and minimizing capital and operating costs.
First developed in 2013, Shell Turbo Technologies (STT) include Shell Turbo Tray, the patented column internal that were deployed since 2021, and have proven highly effective in addressing these issues. STT allow operators to revamp and debottleneck existing units, significantly boosting capacity. For example, retrofitting the trays in an acid gas removal unit (AGRU) absorber in the Middle East led to a 21% increase in gas rates without modifying other equipment. Additionally, the technology has improved gas production by nearly 60% in a triethylene glycol (TEG) dehydration facility.
For existing plants, our new contacting technology can be retrofitted during turnarounds to increase capacity and handle higher concentrations of contaminants. Capable of treating substantially higher contaminants level in the feed gas while maintaining the end-product specifications, the technology offers a simple, cost-effective solution for brownfield projects where the absorber is a bottleneck. By increasing throughput and accommodating feeds with higher contamination, operators can maximize returns and improve operating efficiency. Most operators that are pushing plant capacity will already have installed the latest generations of structured packing or trays, and the new technology means these plants can now increase column capacity by up to 50% more. In some cases, this has avoided the need for additional trains to be added to meet natural gas production targets.
For greenfield projects, the technology can reduce capital expenditure for absorbers/contactors by 30–50%, offering a powerful solution for enhancing operational efficiency and cutting costs.
This presentation will highlight the key benefits of Shell Turbo Tray for gas processors looking to revamp underperforming assets and those planning greenfield applications. Specifically, Shell will:
- summarize technology developed and derisked.
- explain the design fundamentals that enable Shell Turbo Tray to unlock significant performance upgrades.
- present data from two commercial applications: AGRU and TEG dehydration; and
- discuss how this technology can help operators increase processing capacity, tackle operational issues, reduce opex and avoid significant capex.
Session 5: Production of Blue Hydrogen with High Carbon Capture Rates and Energy Efficiency Using Johnson Matthey’s LCHTM Technology
Speaker: Dr Matt Cousins, Johnson Matthey
Abstract: Blue hydrogen is produced through reforming natural gas with carbon capture and storage, achieving a reduction in the product hydrogen carbon intensity of over 70% compared to its unabated equivalent. Autothermal reforming (ATR) is well suited to blue hydrogen production as the energy to drive the reforming reaction is provided by partial combustion of the process stream rather than burning natural gas separately to sustain necessary reaction temperatures in furnace tubes. In an ATR process, the carbon is contained in a high-pressure CO2 stream making 95% capture rates economical.
Johnson Matthey’s LCHTM technology is fundamentally different from other blue hydrogen processes. Instead of simply raising steam, LCHTM technology recovers heat at the maximum possible quality using the gas heated reformer (GHR), to provide energy for 30% of the reforming conversion. The total energy efficiency of blue hydrogen production is increased to over 88% in this configuration.
Session 6: Tackling Net Zero Headwinds
Speaker: David E Simmonds, Energy Consultant (Retired)
Abstract: I published my thoughts on delivering net zero in a series for The Chemical Engineer over the last couple of years. Recently net zero has reached the metaphorical status of a culture war, not least because of the cost, impacting consumers, businesses and industry alike.
The almost universal solution for net zero energy is deployment of renewables and electrification of everything; renewables because they are cheap, and electrification because it offers efficiency. However, as always, the devil is in the detail, and without full system analysis, generalisations can lead to grossly optimistic solutions. Furthermore, policy makers under-estimate the scale of our transition, and I will look to McKinsey’s latest energy study to identify trends.
In my presentation I will explore these headwinds and the public perceptions which are moving political aspirations, and industry’s response. I will also explain that solutions must be geographic, addressing the characteristics of the sun and wind belts. Further they must consider long duration energy storage, which is both market and energy source dependent.
I will conclude by addressing the importance of hydrogen to northern Europe, as it can be stored at scale and offer users more flexibility. In turn we must also look to see what chemical and gas process engineers can do to liberate a plan which can reduce costs through reutilisation of existing infrastructure and engineering skills, rather than building or creating new.
