We are delighted to present our 3-day programme to you. Please note this is subject to change.
Information is being added regularly so do come back!
11:30 - 16:30
“LNG PLANT: TOWARD ZERO EMISSION” Workshop
Marc Fourneraut, TOTAL
09:00 - 10:00
10:30 - 12:00
13:30 - 14:00
Membrane requirements for efficient natural gas sweetening
Patrick Schiffmann, Linde Aktiengesellschaft
Authors: Patrick Schiffmann, Tobias Keller, Alexander Brandl, Christian Voss
Linde Aktiengesellschaft, Linde Engineering
Dr.-Carl-von-Linde-Straße 6-14, 82049 Pullach/Deutschland
Natural gas (NG) has become an increasingly important resource for power production and as feedstock for the chemical industry. But as the worldwide availability of CO2 lean NG decreases, unconventional NG sources with high CO2 concentrations and considerable contents of heavy hydrocarbons (HHC) must be used. Removing CO2 from NG with membranes is a proven technology but, in many cases, conventional membranes lack stability against plasticization and degradation at high CO2 and HHC partial pressures, which increases the frequency of membrane exchanges and reduces the methane recovery.
To treat such gases more efficiently, a highly selective and under NG process conditions stable membrane is essential. Such a membrane has been developed in close cooperation between Evonik and Linde. Extensive laboratory experiments and field data showed an excellent separation performance, HHC resistance and plasticization stability. In various commercial applications, a selectivity of approximately twice the value of conventional membranes has been proven. CO2 could be removed with considerably less hydrocarbon losses and reduced energy requirements. Additionally, the extended long-term stability of this membrane allows an extended replacement cycle and thus reduces downtime and associated costs.
14:00 - 14:30
DDR-type Zeolite Membrane: A practical solution for CO2 separation in the oil and gas industry
Hiroaki Hasegawa, JGC Corporation and NGK Insulators
JGC Corporation (JGC) and NGK Insulators, Ltd. (NGK) are jointly developing the DDR-type zeolite membrane system for CO2 recovery from associated gas and natural gas. This nano porous zeolite membrane prepared on an alumina substrate has advantages such as high CO2/CH4 selectivity compared to conventional membranes, high durability and no restriction on the partial pressure of CO2 for operation. The DDR-type zeolite membrane system can therefore be applied at high pressure and with high CO2 concentration in gas production where conventional polymeric membranes can be significantly plasticized and lose their performance.
JGC and NGK have already completed the laboratory testing of the DDR-type zeolite membrane to confirm resilience and performance at high pressure and high CO2 concentration and assess the effect of impurity components. The DDR-type zeolite membrane system is now at the demonstration test stage where JGC has prepared and operated a DDR-type zeolite membrane system which can treat 3 MMSCFD of associated gas. The aim of the test is to evaluate the superior performance and the long-term durability of the membrane system using actual gas in a real CO2-EOR field. In this paper, up-to-date information for the membrane and progress on the demonstration test will be introduced.
15:00 - 15:30
"LNG in a Low Carbon World – A Roadmap to Decarbonize"
Jason Frost and Tim Cuttance, Aker Solutions
With energy companies moving towards a lower carbon future with increasing commitments to Net Zero emissions in the next 30-40 years, focus has shifted to minimizing the emissions associated with production of hydrocarbons.
Gas is still recognized as a transitional fuel in the energy supply, with increasing focus on carbon capture and storage as a means of converting the fuel to cleaner energy. Therefore, it is important to consider and minimize the emissions associated with the production of LNG.
This technical paper presents a roadmap to decarbonize LNG production facilities through:
utilization of the most appropriate technologies and equipment;
integration of renewable energy/high efficiency power plants;
technology efficiency optimization and design for carbon capture or carbon capture ready.
It will include an introduction to a cost effective modular carbon capture facility using state-of—the-art solvent technology, which can be incorporated into both new build greenfield facilities as well as existing plants.
We will demonstrate the various pathways to lower the CO2 per mass of LNG produced.
15:30 - 16:00
Turbomachinery Configuration for LNG Projects - Conceptual Selection
Mounir MOSSOLLY, TechnipFMC
Céline BELBOL, TechnipFMC
Refrigerant compressors are the pumping heart of any liquefied natural gas plant. Those compressors are centrifugal type, they vary in size and configuration, being influenced by the context of the project. Steam turbines, gas turbines (heavy duty or aero-derivative) and/or electric motors are all possible options to drive the refrigerant compressors. A single shaftline could couple one, two or three compressor casings depending on the liquefaction process technology and process balancing needs, and also linked to the output power(s) of the possible drivers options. This paper will technically elaborate on how decisions are technically made for selecting the optimum turbomachinery configuration of refrigerant compressors in LNG plants. The paper will list the various criteria that could be initially set (and given an importance weight), which shall be used as a basis for evaluation and decision making. Technical constraints that could be faced will also be discussed. This paper builds on technical experience attained through working on several conceptual and pre-FEED studies for turbomachinery selection in LNG projects.
16:00 - 16:30
The Acorn Carbon Capture and Storage Project
Adam Jones, Costain
The Acorn CCS project is a low-cost, low-risk, scalable, carbon capture and storage scheme that will not only enable the cost efficient carbon capture and storage of current carbon emissions from the onshore gas facilities at St Fergus, but is also a key enabler for the Acorn Hydrogen project where North Sea natural gas will be reformed into clean hydrogen. It is designed to be built quickly, taking advantage of existing oil and gas infrastructure and a well understood offshore CO2 storage site. The system is designed to be an enabler of other capture and storage projects including provision of CO2 shipping facilities in Peterhead Port and repurposing the existing Feeder 10 pipeline to enable capture of CO2 from wider regions. The project is led by Pale Blue Dot Energy Ltd supported by study partners Shell, Total and Chrysaor with Costain providing onshore and offshore facilities engineering and consultancy services.
09:00 - 09:10
09:10 - 09:40
Sour Water Stripper Challenges with Preventative Mitigation and Enhancement Efforts
Authors: Paul, Mishar K and Omar Aljamea, Haradh Gas Plant Department, Saudi Aramco
HdGP sour water stripper (SWS) unit is designed to remove acid gas mainly H2S and CO2 as well as oil & grease to produce waste water prior to send to the waste water evaporation ponds by processing the plant feeds separated from gas and condensate through three phase separators (slug catchers and separators). There are two identical trains, each with design capacity of 185 GPM. The contaminated sour water is first processed through the de-oiling hydro cyclone to remove most of the oil & grease. The acid gas then stripped-off from the sour water through the pre-flash drum and stripper column to meet the waste water specification of H2S, pH and oil & grease contents. Operating each SWS unit was challenging due to overpressure buildup, de-oiler inefficiency, polishing filter high DP, high stripper column temperature, stripped water pump and reflux pump failure, unstable reflux drum level and reflux flow caused by uncontrolled flow above design and high HC carry over for frequent slugging of the slug catchers. As a result, stripped water gets off-spec frequently mainly high oil & grease and high solid contents, which impacts on the environment as well as overloading the waste water evaporation ponds in addition to SWS frequent operational upsets, which increasing the plant operating cost and at the same time, frequent dumping water to wet HC burn-pit to minimize slugging, consequences damage of the burn-pit. The overpressure also contributing for excessive flaring. The root causes were identified and several enhancement efforts were instigated in order to minimize the environmental impact as well as to reduce plant operating cost. This paper will share the short and long terms preventive, mitigation and enhancement efforts for the improvement includes both operating parameters and design changes to overcome the challenges.
Keywords: Haradh gas plant (HdGP), gallons per minute (GPM), differential pressure (DP), hydro carbon (HC).
09:40 - 10:10
Sohar LNG Bunkering project in Oman
10:45 - 11:15
How a poor prediction of absorber temperature can significantly impact Amine Unit efficiency
Speakers: Carmella Alfano, AXENS and Céline Volpi, TOTAL
Carmella Alfano, Clément Salais, Géraldine Laborie, Manuela Arratia, AXENS, Rueil-Malmaison, France
Céline Volpi, Stefano Langé, Renaud Cadours, Claire Weiss, TOTAL, Paris La Défense, France
Designers / Licensors of amine sweetening units are subject to increasingly fierce competition which requires them to offer the amine solvent flow rate and absorption column height as fair as possible in order to be awarded. Defining a tight design requires having a valid and robust simulation model framework to best calculate the expected performance of the column. The calculation of the temperature profile within the absorber often plays a largely underestimated role during the design phases not only on the treated gas quality from the unit but also on the sizing of the equipment which can call into question the operability of even the gas plant. We will discuss in this article the impact of a poor prediction of the absorber temperature profile on the future capacity of the unit, on the sizing of the equipment and on the downstream units. A dedicated case study as well as operational data from a pilot plant unit will illustrate the discussion.
11:15 - 11:45
Sorbent-based Process for Organic Sulfur Removal from Natural Gas and Natural Gas Liquids
Gokhan O. Alptekin, PhD, SulfaTrap LLC
While the conventional acid gas removal systems based on amine scrubbing and caustic treatment are highly effective in removing hydrogen sulfide (H2S) and simple mercaptans from natural gas and natural gas liquids, these technologies are not highly effective for the removal of complex organo-sulfur compounds such as complex mercaptans (e.g., isopropyl mercaptan, tert-butyl mercaptan), sulfides (dimethyl sulfide, carbonyl sulfide), thiophenes (alkyl thiophenes) and disulfides (e.g., di methyl disulfide, carbonyl disulfide or methyl ethyl disulfide).
SulfaTrap LLC is offering a new sorbent-based desulfurization processes that can remove organic sulfur contaminants from natural gas and natural gas liquids (NGL). The desulfurization system uses a new proprietary adsorbent that can achieve a very high sulfur capacity and removal efficiency. The sorbent is regenerated by applying a mild temperature swing cycle, with low energy input resulting in a cost effective process.
The paper will provide the details of the new technology and the results of large-scale pilot experiments showing the capabilities of processing natural gas and biogas, as well as from natural gas liquids (C4+ streams). The results of several field tests at the gas processing facilities and refineries at the pilot scale suggest that the new technology can be successfully used in the treatment of a wide range of feedstocks containing different types of sulfur contaminants, with treated product meeting the sale gas/liquid product specification. The sorbent maintains its chemical activity and mechanical durability for extended cycles. High fidelity economic evaluations for stand-alone units treating NGL streams and polishers integrated with the conventional Acid Gas Removal Units (AGRUs) for natural gas treatment suggests favorable economics for the new technology.
11:45 - 12:15
Demonstration of the next generation solvents for super selective H2S removal in a commercial tail gas treatment unit
13:45 - 14:15
Energy transition: threat or opportunities?
Christian Bladanet, TechnipFMC
Today, clean, carbon free, green energies make all the talk. Is it the bell tolls of the natural gas industry ?
For decades, the natural gas industry has been working toward improving the wellbeing of the humanity, by providing cheap, cleaner and abundant energies. During this journey, our industry has continuously developed technologies improving the efficiency and emissions of the gas processing facilities.
This paper will present how members of GPA Europe (producers, contractors and suppliers) are uniquely positioned to build on existing technologies, know-how and experiences to bring new, cleaner, potentially carbon free, energies to the world and generate a renewed growth through the energy transition path.
14:15 - 14:45
GERG (the European Gas Research Group) completes first stage of flagship biomethane project for CEN and the European Commission
Marine Juge, ENGIE Lab CRIGEN
GERG is pleased to announce the successful completion of the first phase of the European Commission funded project on removing barriers to biomethane injection in the natural gas grid and use as a vehicle fuel.
There is huge potential for biomethane transported in the gas network to play a significant part in decarbonisation of our energy system. As a substitute for natural gas, it allows use of existing infrastructure, while complementing intermittent renewable energy sources. However, some contaminants, inherent to the biomethane production processes, can be present in biomethane at a trace level. Depending on their concentration, these trace components (not present in natural gas) can interact with the gas chain infrastructure, and engines and boilers.
Two standards regarding biomethane have been published
• EN 16723-1: specifications for biomethane for injection in the natural gas network;
• EN 16723-2: automotive fuels specifications.
Limit concentration values are however lacking real world data. This can be a barrier for the development of biomethane in Europe as limits can be over prescriptive. For this reason, GERG and CEN launched a project in 2016 with the aim to identify the associated acceptable threshold for gas appliances and infrastructure. This paper present the results of the project.
15:30 - 16:00
An industrial and experimental case studies on hydrate prediction and inhibition
Nejat Rahmanian, University of Bradford
Formation of natural gas hydrates can cause serious problems during drilling and production operations in the oil and gas industry. This investigation reports the first study to predict hydrate formation using Aspen HYSYS® and HydraFlash softwares for various gas compositions and thermodynamic inhibitors (MEG concentrations at 10, 20, 30 and 40 𝑤𝑡% and Methanol concentrations at 10 and 20 𝑤𝑡%). Aspen HYSYS® is widely used in the petroleum process system containing thermodynamic inhibitor for this crucial purpose on prediction of solid phase behaviour. The simulated predictions are compared with results of available industrial and experimental data in the literature. It has been shown that HydraFlash software can accurately predict hydrate formation condition for a given industrial case, without having to carry out costly experimental work. This work also looked the effect of inhibitors and it appears that inhibitor type and concentration are determined according to condition of gas composition. MEG is consequently selected as the most ideal hydrate inhibitor for the industrial case. The hydrate formation prediction was carried out by HydraFlash for a high concentration of MEG inhibition at 40 𝑤𝑡% is up to 313 K with a pressure of 3111 𝑏𝑎𝑟. Finally, it is shown that both software packages are quite accurate and useful tools for prediction of hydrate for simple systems. However, HydraFlash can simulate more complex systems, including 13 different types of salts, while so Aspen Hysys covers sodium hydroxide as the common salt.
16:00 - 16:30
Optimized CO2 capture with DMX™ process
Speaker: Xavier COURTIAL, Axens
Authors: Axens, IFP Energies Nouvelles, TOTAL Refining & Chemicals and ARCELORMITTAL ATLANTIQUE ET LORRAINE SAS
CO2 capture & storage is foreseen as a necessity to limit global warming, as indicated by the International Energy Agency in the 2D scenario. Major initiatives have to be initiated in a near future with concrete actions to get efficient results in limiting global warming. DMX™ process is foreseen as a key driver to initiate such transition in the industrial world. This process is based on a second-generation amine solvent, allowing to drastically reducing CO2 capture cost in comparison to more conventional solvent such as MEA and others available solvents.
Based on the actual knowledge, techno-economic studies have been performed for 3 study cases and show significant advantage of DMX™ technology relatively to MEA : up to 30 % reduction in OPEX can be obtained for lower or similar CAPEX, depending on the condition.
Such performance would be demonstrated within the H2020 3D Project, based on pilot test on real industrial gas from ArcelorMittal steel mill plant in Dunkirk (France). The H2020 3D Project could also study the whole value chain for an industrial CCS application linking ArcelorMittal plant in Dunkirk to potential storages in the North Sea. The 3D Project coordinated by IFPEN involves 11 companies and academic partners from Europe.